BEFORE THE PUBLIC UTILITIES COMMISSION OF THE · PDF fileBEFORE THE PUBLIC UTILITIES COMMISSION OF THE STATE OF CALIFORNIA Alliance for Nuclear Responsibility, Complainant, ... 31

BEFORE THE PUBLIC UTILITIES COMMISSION OF THE

STATE OF CALIFORNIA

Alliance for Nuclear Responsibility, Complainant,

vs.

Southern California Edison Company (U338E), Defendant.

Case No. C. 13-02-013 (Filed February 19, 2013)

SOUTHERN CALIFORNIA EDISON COMPANY’S (U 338-E) MOTION TO DISMISS COMPLAINT BY THE ALLIANCE FOR NUCLEAR

RESPONSIBILITY

DOUGLAS K. PORTER WALKER A. MATTHEWS RUSSELL A. ARCHER Southern California Edison Company 2244 Walnut Grove Avenue Post Office Box 800 Rosemead, CA 91770 Telephone: (626) 302-6879 Facsimile: (626) 302-3990 E-mail: [email protected]

HENRY WEISSMANN JONATHAN E. ALTMAN JOHN B. OWENS LIKA C. MIYAKE Munger, Tolles & Olson LLP 355 South Grand Avenue, 35th Floor Los Angeles, CA 90071 Telephone: (213) 683-9150 Facsimile: (213) 683-5150 E-mail: [email protected]

Dated: April 10, 2013

TABLE OF CONTENTS

Page

-i-

I. INTRODUCTION AND SUMMARY OF ARGUMENT .................................... 1

II. BACKGROUND ................................................................................................... 3

A. Factual Background ................................................................................... 3

1. SGRP Costs As “Reasonableness Threshold” ............................... 4

2. Establishment Of Balancing Accounts And Recovery Of Costs In Rates ................................................................................ 6

B. Procedural Background .............................................................................. 9

III. ARGUMENT ....................................................................................................... 11

A. The Commission Lacks Jurisdiction Over The Majority Of Claims In The A4NR Complaint .......................................................................... 11

1. The Commission Lacks Jurisdiction Over Claims Based On Violations Of Federal And State Law .......................................... 11

2. The Commission Lacks Jurisdiction Over Claims Alleging Wrongdoing By Edison International .......................................... 12

B. A4NR Has Failed To State A Claim For A Rule 1.1 Violation. .............. 13

C. A4NR Has Not Come Close To Alleging Violations Of The Federal And State Statutes It Asks The Commission To Enforce ........... 14

1. A4NR’s Securities Fraud Claims Fail .......................................... 15

2. A4NR’s False Claims Act Claims Also Fail................................ 21

3. A4NR Has Failed To State A Claim Under California’s Unfair Competition Law. ............................................................. 25

D. The Commission Should Not Initiate A Lawsuit Based On A4NR’s Complaint ................................................................................................. 26

E. The Complaint Is An Improper Attempt To Circumvent The OII ........... 26

IV. CONCLUSION .................................................................................................... 28

TABLE OF AUTHORITIES

Page

-ii-

STATE CASES

Assembly v. PUC, 12 Cal. 4th 87 (1995) ...................................................................................................13

California Amplifier, Inc. v. RLI Ins. Co., 94 Cal. App. 4th 102 ..................................................................................13, 20, 21, 26

Californians for Disability Rights v. Mervyn’s, LLC, 39 Cal. 4th 223 (2006) .................................................................................................25

Cel-Tech Commc’ns., Inc. v. Los Angeles Cellular Tel. Co., 20 Cal. 4th 163 (1999) .................................................................................................20

County of Kern v. Jadwin, 197 Cal. App. 4th 65 (2011) ........................................................................................28

Farmers Ins. Exchange v. Superior Court, 2 Cal. 4th 377 (1992) ...................................................................................................25

Goodspeed v. Great Western Power Co., 33 Cal. App. 2d 245 (1939) .........................................................................................11

Greenlining Inst. v. PUC, 103 Cal. App. 4th 1324 (2002) ..............................................................................11, 12

Kwikset Corp. v. Superior Court, 51 Cal. 4th 310 (2011) .................................................................................................25

Mao’s Kitchen, Inc. v. Mundy, 209 Cal. App. 4th 132 (2012) ......................................................................................22

Motor Transit Co. v. Railroad Comm’n, 189 Cal. 573 (1922) .....................................................................................................11

Northern Cal. Power Agency v. PUC, 5 Cal. 3d 370 (1971) ....................................................................................................11

People ex rel. Orloff v. Pac. Bell, 31 Cal. 4th 1132 (2003) ...............................................................................................26

PG&E Corp. v. PUC, 118 Cal. App. 4th 1174 (2004) ...................................................................................12

TABLE OF AUTHORITIES (continued)

Page

- iii -

State ex rel. Grayson v. Pac. Bell Tel. Co., 142 Cal. App. 4th 741 (2006) ......................................................................................22

State ex rel. McCann v. Bank of America, N.A., 191 Cal. App. 4th 897 (2011) ......................................................................................22

Wise v. Pacific Gas & Elec. Co., 77 Cal. App. 4th 287 (1999) ........................................................................................12

FEDERAL CASES

Berson v. Applied Signal Tech., Inc., 527 F.3d 982 (9th Cir.2008) ........................................................................................18

Blue Chip Stamps v. Manor Drug Stores, 421 U.S. 723 (1975) .....................................................................................................15

Bly-Magee v. California, 236 F.3d 1014 (9th Cir. 2001) ...............................................................................22, 23

Chabner v. United of Omaha Life Ins. Co., 225 F.3d 1042 (9th Cir. 2000) .....................................................................................25

County of Santa Clara v. Astra United States, Inc., 428 F. Supp. 2d 1029 .............................................................................................23, 24

Crookham v. Crookham, 914 F.2d 1027 (8th Cir. 1990) ...............................................................................15, 28

Desaigoudar v. Meyercord, 223 F.3d 1020 (9th Cir. 2000) .....................................................................................16

Dura Pharm., Inc. v. Broudo, 544 U.S. 336 (2005) .....................................................................................................16

Fox v. Acadia State Bank, 937 F.2d 1566 (11th Cir. 1991) .............................................................................15, 28

Fru-Con Const. Corp. v. Sacramento Mun. Utility Dist., No. CIV. S-05-583 LKK/GGH, 2007 WL 1791699 (E.D. Cal. June 15, 2007) ..........23

Halkin v. VeriFone Inc. (In re VeriFone Sec. Litig.), 11 F.3d 865 (9th Cir. 1993) .........................................................................................18


Page

- iv -

Hollinger v. Titan Capital Corp., 914 F.2d 1564 (9th Cir. 1990) .....................................................................................21

In re Coinstar Inc. Sec. Litig., No. C11-133 MJP, 2011 WL 4712206 (W.D. Wash. Oct. 6, 2011) ............................16

In re Cutera Sec. Litig., 610 F.3d 1103 (9th Cir. 2010) .....................................................................................18

In re Silicon Graphics Sec. Litig., 183 F.3d 970 (9th Cir. 1999) .......................................................................................19

In re Wash. Pub. Power Supply Sys. Sec. Litig., 823 F.2d 1349 (9th Cir. 1987) .....................................................................................15

Ontario Pub. Serv. Employees Union Pension Trust Fund v. Nortel Networks Corp., 369 F.3d 27 (2d Cir. 2004)...........................................................................................16

Ronconi v. Larkin, 253 F.3d 423 (9th Cir. 2001) .......................................................................................19

Rubke v. Capitol Bancorp Ltd., 551 F.3d 1156 (9th Cir. 2009) .....................................................................................16

Tellabs, Inc. v. Makor Issues & Rights, Ltd., 551 U.S. 308 (2007) .....................................................................................................19

TSC Indus., Inc. v. Northway, Inc., 426 U.S. 438 (1976) .....................................................................................................18

United Paperworkers Int’l Union v. Int’l Paper Co., 985 F.2d 1190 (2d Cir. 1993).......................................................................................18

United States ex rel. Hendow v. Univ. of Phoenix, 461 F.3d 1166 (9th Cir. 2006) .....................................................................................22

United States ex rel. Herndon v. Science Applications Int’l Co., No. 05CV2269-BEN, 2007 WL 2019653 (S.D. Cal. July 10, 2007) ..........................24

United States ex rel. Longstaffe v. Litton Indus., Inc., 296 F. Supp. 2d 1187 (C.D. Cal. 2003) .......................................................................22

United States ex rel. Roby v. Boeing Co., 100 F. Supp. 2d 619 (S.D. Ohio 2000) ........................................................................23


Page

- v -

United States ex rel. UNITE HERE v. Cintas Corp., No. C 06-2413 PJH, 2008 WL 1767039 (N.D. Cal. Apr. 16, 2008)............................23

United States v. Dan Caputo Co., 321 F.3d 926 (9th Cir. 2003) .......................................................................................24

Veltex Corp. v. Matin, No. CV 10-1746 ABC (PJWx), 2010 WL 3834045 (C.D. Cal. Sept. 27, 2010) .........15

WPP Luxembourg Gamma Three Sarl v. Spot Runner, Inc., 655 F.3d 1039 (9th Cir. 2011) .....................................................................................19

CALIFORNIA STATUTES AND RULES

Cal. Bus. & Prof. Code §§ 17200, et seq. ..................................................................2, 9, 25

Cal. Bus. & Prof. Code § 17203 ........................................................................................25

Cal. Bus. & Prof. Code § 17204 ..................................................................................25, 26

Cal. Bus. & Prof. Code § 17535 ........................................................................................26

Cal. Code Civ. Proc. § 437(c) ............................................................................................14

Cal. Corp. Code § 25400................................................................................2, 9, 13, 20, 21

Cal. Corp. Code § 25500....................................................................................................20

Cal. Corp. Code § 25530....................................................................................................13

Cal. Corp. Code § 25532....................................................................................................13

Cal. Corp. Code § 25535....................................................................................................13

Cal. Gov. Code § 12650, et seq. ..........................................................................................9

Cal. Gov. Code § 12651 .....................................................................................................23

Cal. Gov. Code § 12652 .........................................................................................21, 22, 26

Cal. Pub. Util. Code § 701 ...........................................................................................11, 13

Cal. Pub. Util. Code § 2101 ...........................................................................................9, 26


Page

- vi -

Cal. Pub. Util. Code § 2102 ...............................................................................................26

Commission Rule of Practice and Procedure Rule 1.1 ........................................1, 9, 13, 14

Commission Rule of Practice and Procedure Rule 1.8 ......................................................28

Commission Rule of Practice and Procedure Rule 4.2 ........................................................3

FEDERAL STATUTES, REGULATIONS, AND RULES

15 U.S.C. § 77q ..........................................................................................................1, 9, 15

15 U.S.C. § 77t ............................................................................................................13, 26

15 U.S.C. § 78ff ...........................................................................................................13, 26

15 U.S.C. § 78j ...........................................................................................................2, 9, 15

15 U.S.C. § 78u ............................................................................................................13, 26

31 U.S.C. § 3729 ......................................................................................................9, 22, 23

31 U.S.C. § 3730 ....................................................................................................21, 22, 26

Fed. R. Civ. P. 9(b) ......................................................................................................16, 22

17 C.F.R. § 240.10b-k ........................................................................................................15

ADMINISTRATIVE DECISIONS

D. 99-11-023, 1999 WL 1957792 (Nov. 4, 1999) .............................................................13

D. 04-05-006, 2004 WL 1095245 (May 26, 2005) ............................................................14

D. 05-12-040, 2005 WL 3540902 (Dec. 15, 2005) ..................................................3, 4, 5, 8

D. 11-05-035, 2011 WL 2246054 (May 26, 2011) ..................................................3, 4, 5, 8

D. 12-03-037, 2012 WL 1135830 (Mar. 22, 2012) ...........................................................14

D. 13-01-001, 2013 WL 265502 (Jan. 10, 2013) ...............................................................14


Page

- vii -

OTHER AUTHORITIES

HAROLD MARSH, JR. & ROBERT H. VOLK, PRACTICE UNDER CALIFORNIA SECURITIES LAWS (REV. ED. 2012) ..................................................................................................21

THOMAS LEE HAZEN, THE LAW OF SECURITIES REGULATION (6TH ED. 2009). ..................15

- 1 -

I. INTRODUCTION AND SUMMARY OF ARGUMENT

On February 13, 2013, the Alliance for Nuclear Responsibility (“A4NR”) first

attempted to file its complaint against Southern California Edison (“SCE”) and Edison

International (“EIX”), alleging causes of action for securities fraud, violations of the state

and federal false claims acts, and unfair competition. The Commission immediately

rejected the complaint, explaining that the Commission lacked jurisdiction over A4NR’s

claims. Three days after the Commission’s rejection, A4NR filed essentially the same

complaint (the “Complaint”), once again alleging exactly the same five defective causes

of action over which the Commission has already ruled it lacked jurisdiction, but—in an

effort to avoid the Commission’s correct jurisdictional ruling—adding a new cause of

action for an alleged violation of Commission Rule of Practice and Procedure 1.1 (“Rule

1.1”). With the addition of the new cause of action, the Commission permitted the

Complaint to be served. A4NR’s Complaint is frivolous and should be dismissed.

First, the Commission has already correctly held that it has no jurisdiction over

five of A4NR’s six causes of action.

Second, A4NR’s cause of action under Rule 1.1—the one claim the Commission

has not already rejected—fails because SCE did not mislead the Commission or its staff.

Contrary to A4NR’s conclusory allegation, SCE did not use an inflation adjustment in

Advice Letters 2355-E, 2521-E, 2648-E-A, and 2834-E.

Third, A4NR’s five statute-based claims fail on the merits, even if the

Commission had jurisdiction to consider them. Their numerous deficiencies include:

� No allegation appears that A4NR has ever attempted to buy or sell a single SCE

or EIX security, as required to state a claim under the federal securities laws.

� A4NR has no standing to bring its federal securities fraud claim based on 15

U.S.C. § 77q(a) (Section 17(a) of the Securities Exchange Act of 1933), which

does not provide a private right of action.

- 2 -

� A4NR’s securities fraud claim based on 15 U.S.C. § 78j(b) (Section 10(b) of the

Securities Exchange Act of 1934) fails because A4NR fails to allege facts

sufficient to meet any of the required elements of a Section 10(b) claim, notably

failing even to attempt to allege that SCE’s or EIX’s statements were materially

false, that any investor relied on any SCE or EIX statement, or that such reliance

resulted in harm.

� For similar reasons, A4NR’s securities fraud claim based on Cal. Corp. Code

§ 25400(d) fails. In addition to failing to allege that any security was sold, or

offered to be sold, A4NR’s Complaint fails each element of a Cal. Corp. Code

§ 25400(d) claim, including failing to allege materiality or that the price of any

security was affected by SCE’s or EIX’s statements at issue.

� A4NR accuses SCE of violating federal and state False Claims Acts without

identifying a single allegedly false claim, or that any supposed false claim would

have been material to a government decisionmaker or caused any government

entity to pay.

� A4NR’s False Claims Act allegations are not only substantively meritless, but

procedurally deficient. A4NR has failed to satisfy the prerequisite procedural

requirements for bringing False Claims Act claims—that such claims be filed in

court and under seal, and be concurrently served on a government prosecutor.

� A4NR contends that SCE violated the California Unfair Competition Law, Cal.

Bus. & Prof. Code §§ 17200, et seq. (“UCL”), even though A4NR has suffered no

injury that could give it standing to sue under that statute.

� Aside from having no standing to bring a California UCL claim, A4NR has failed

to demonstrate violations of any statute or rule that could serve as a predicate

violation upon which its UCL “unlawfulness” claim could be based.

Indeed, it appears that A4NR did not make even a minimal effort to learn or

allege the essential elements of any of the causes of action in its Complaint. In any event,

- 3 -

as set forth in greater detail below, none of them are plausibly pled, nor could they be.

SCE respectfully requests that the Commission dismiss A4NR’s Complaint with

prejudice. Should the Commission decide to not dismiss part or all of A4NR’s

Complaint, the Commission should refer it to Commission staff for informal resolution

pursuant to Commission Rule 4.2(c).

The Commission should reject A4NR’s request for this Commission to initiate its

own lawsuit concerning A4NR’s allegations. This request is merely another attempt by

A4NR to skirt the limitations on the Commission’s power to consider these claims. A

Commission lawsuit would suffer from the same jurisdictional, procedural, and

substantive deficiencies as the A4NR’s complaint.

II. BACKGROUND

A. Factual Background

On December 15, 2005, the Commission issued Decision (“D.”) 05-12-040 (the

“SGRP Approval Decision”), approving SCE’s request to replace SONGS Units 2 and

3’s four original steam generators (the Steam Generator Replacement Project, or SGRP).

In that decision, the Commission made two orders relevant to the issues raised in A4NR’s

Complaint concerning the costs of the SGRP and how those costs could ultimately be

included in SCE’s rates.

1. SGRP Costs As “Reasonableness Threshold”

First, the Commission ordered SCE to apply to include the full costs of the SGRP

into rates once the SGRP was completed. D. 05-12-040, 2005 WL 3540902 at *46 (Dec.

15, 2005) (Ordering Paragraph (“OP”) 11). The Commission approved a “reasonable

cost estimate” for SGRP costs of $680 million in 2004 dollars. Id. (OP 3). The

reasonableness threshold was subsequently reduced to $670.8 million pursuant to D. 11-

05-035, 2011 WL 2246054 (May 26, 2011). This figure was set as a threshold to help

determine whether the level of costs incurred for the SGRP would be subject to a

- 4 -

reasonableness review at the time of the application to include the full costs of the SGRP

into rates: “We do not intend to conduct an after-the-fact reasonableness review if the

SGRP cost does not exceed $680 million [modified to $670.8].” Id. at *46 (OP 4). At

the time of the SGRP Approval Decision, the Commission did not prescribe an inflation

adjustment in connection with the costs discussed in the Decision. The Commission

noted that an inflation adjustment would be required to determine whether the costs

incurred should be subject to reasonableness review, and suggested that “[t]he inflation

adjustment should be made based on reliable publications such as the Consumer Price

Index published by the U.S. Bureau of Labor Statistics.” Id. at *42 (Findings of Fact

(“FOF”) ¶¶ 148-49). It further determined that the existing record was insufficient to

determine how such an inflation adjustment should be made. Id. (FOF ¶ 150).

On March 15, 2013, SCE filed its Application for inclusion of the SGRP costs

permanently in rates (A. 13-03-005 or the “SGRP Cost Review Application”). In the

testimony accompanying the SGRP Cost Review Application (SCE-6, submitted in I. 12-

10-013 (the “SONGS OII”), at 1-2), SCE noted that the Commission had not set a

specific inflation adjustment to apply to the SGRP costs for purposes of determining

whether the costs fell below the reasonableness threshold in 2004 dollars. SCE’s

testimony demonstrates that SCE’s actual SGRP costs are well below the reasonableness

threshold based on deflation of actual expenditures to 2004 dollars using the Handy-

Whitman Index of Public Utility Construction Costs and the burial escalation rates

approved by the Commission in other proceedings. The testimony also explains why the

Handy-Whitman Index and the burial escalation rate are the most appropriate indices to

use in calculating the deflation adjustment for SGRP costs. SCE-6 at 4-12. The SGRP

Cost Review Application, including the question of what deflation adjustment will be

used to determine whether SCE met the reasonableness threshold, is still pending.

In their securities filings and in other statements to investors since the SGRP

Approval Decision, SCE and EIX have regularly reported the approximate costs incurred

- 5 -

in connection with the SGRP. In those statements, SCE and EIX have compared those

expenditures against the $670.8 million reasonableness threshold, appropriately adjusted

for inflation to permit an apples-to-apples comparison between recorded SGRP costs

(which have occurred in the years since the SGRP Approval Decision) and the

reasonableness cost threshold (which was set in 2004 dollars). A4NR alleges that SCE,

and its holding company, EIX, made material misrepresentations to investors in these two

statements: (1) that EIX CEO Theodore F. Craver, Jr. used the phrase “inflation-adjusted

authorized spend” in an earnings conference call, and (2) that in securities filings, EIX

and SCE included the phrase “the CPUC authorized expenditures of approximately $525

million1 ($665 million when adjusted for inflation).” Compl. ¶¶ 14-17. These phrases,

A4NR contends, shows that SCE and EIX told investors that the Commission had

authorized an inflation adjustment to be applied to SGRP costs. Compl. ¶15. A4NR’s

interpretation is inadvertently confused at best, deliberately misleading at worst, and in

any event, wrong.

2. Establishment of Balancing Accounts And Recovery Of Costs In Rates

Second, the Commission ordered that SCE could recover, on an interim basis, its

revenue requirement related to the SGRP based on its recorded expenditures. D. 05-12-

040 at *46 (OP 9-10). The Commission permitted SCE to record in balancing accounts

the revenue requirement associated with the steam generator replacement (the SONGS

2&3 Steam Generator Replacement Balancing Account, or SGRBA) and revenue

requirement associated with the removal and disposal of the original steam generators

(the SONGS 2&3 Steam Generator Removal and Disposal Balancing Account, or

SGRDBA). Id. (OP 7-8). Through these balancing accounts, SCE would track and

1 $525 million is SCE’s approximate proportion of the $670.8 million reasonableness threshold amount ($670.8 million multiplied by SCE’s ownership share in SONGS of 78.21% equals approximately $525 million).

- 6 -

record the actual costs for the SGRP as those costs were incurred over the course of the

SGRP. The Commission also permitted SCE to include the revenue requirement

associated with the balancing accounts in rates on an interim basis, subject to refund, at

the beginning of the year following (a) commercial operation of each unit; and (b) the

completion of the removal and disposal of the original steam generators for each unit. Id.

(OP 9-10).

As ordered by the Commission, SCE filed Advice Letter 2355-E to establish the

SGRBA and SGRDBA and to modify the existing Base Revenue Requirement Balancing

Account (“BRRBA”). The SGRBA was established as a part of SCE’s tariff schedules in

Preliminary Statement, Part Z, “to record SCE’s ownership share of its actual steam

generator replacement costs revenue requirements.” Advice Letter 2355-E at 2; see also

id. at Preliminary Statement, Part Z, Sheet 1.2 The SGRDBA was established as a part of

SCE’s tariff schedules under Preliminary Statement, Part SS, “to record SCE’s ownership

share of its actual steam generator removal and disposal costs revenue requirements,”

except for 20% of estimated removal and disposal costs, which SCE was allowed to

recover from 2006 to 2011. Id. at 3; see also id. at Preliminary Statement, Part SS, Sheet

1.3 The tariff permits SCE to record only its actual, recorded costs – for example, Book 2 The SGRBA consisted of two sub-accounts (the SONGS Unit 2 SGR Sub-account and SONGS Unit 3 SGR Sub-account), one each for the recorded activity associated with Unit 2 and Unit 3, respectively. Each sub-account contained the following entries recording actual revenue requirements associated with the SGRP for that unit: “a. Debit entry - recorded Book Depreciation Expense; b. Debit entry - recorded Ad Valorem Tax Expense; c. Debit entry - recorded Tax Expense Based on Income, including all appropriate income tax adjustments, and deferred income tax expense; and d. Debit entry- recorded Return on Rate Base (which is one-twelfth of the Rate of Return on Rate Base, multiplied by the average SONGS Unit [2 or 3] SGR rate base for the month).” Advice Letter 2355-E, Preliminary Statement, Part Z, Sheets 4-5. Cost forecasts derived from recorded costs and forecasts of capital costs were recovered and then “trued up” to be consistent with the recorded costs reflected in the SGRBA. Snow Decl. Ex. 1 (SCE-5 at 4-7). 3 The SGRDBA consisted of two sub-accounts (the SONGS Unit 2 SGRAD Sub-account and SONGS Unit 3 SGRAD Sub-account), one each for the recorded activity associated with Unit 2 and Unit 3, respectively. Each sub-account contained the following entries

- 7 -

Depreciation Expense. The tariff does not permit SCE to apply an inflation adjustment to

its recorded costs.

SCE then filed three Advice Letters to implement the Commission’s order which

authorized SCE to include certain SGRP-related revenue requirements in rates on an

interim basis, subject to refund:

� Advice Letter 2521-E, filed November 1, 2010, implemented the estimated

2011 revenue requirement to be included in rates beginning January 1, 2011,

for the replacement of the Unit 2 steam generators. Advice Letter 2521-E was

approved by the Energy Division on December 7, 2010, and made effective as

of December 1, 2010.

� Advice Letter 2648-E-A, filed November 1, 2011, implemented the 2012

revenue requirements to be included in rates beginning January 1, 2012,

including estimated revenue requirements for the SGRP relating to both Units

2 and 3. Advice Letter 2648-E-A was approved by the Energy Division on

June 13, 2012, and made effective as of January 1, 2012.

� Advice Letter 2834-E, filed December 31, 2012, implemented the 2013

revenue requirements to be included in rates beginning January 1, 2013,

including estimated revenue requirements for the Units 2 and 3 SGRP and the

replacement and disposal of both Unit 2 and 3’s original steam generators.

This Advice Letter is still pending.

recording actual revenue requirements associated with the removal and disposal costs for the original steam generators of that unit: “Debit entry - recorded Ad Valorem Tax Expense; b. Debit entry - recorded Tax Expense Based on Income, including all appropriate income tax adjustments, and deferred income tax expense; and c. Debit entry - recorded Return on SGRAD Rate Base (which is one-twelfth of the Rate of Return on Rate Base, multiplied by the average SONGS Unit [2 or 3] SGRAD rate base for the month).” Advice Letter 2355-E, Preliminary Statement, Part SS, Sheets 3-4. Cost forecasts derived from recorded costs and forecasts of capital costs were recovered and then “trued up” to be consistent with the recorded costs reflected in the SGDRBA. Snow Decl. Ex. 1 (SCE-5 at 4-7).

- 8 -

Consistent with the language of the tariffs, in none of the calculations used to

determine the SGRP revenue requirements submitted in the above-referenced “Relevant

Advice Letters” (Advice Letters 2355-E, 2521-E, 2648-E-A, and 2834-E) did SCE use an

inflation adjustment or escalation factor. Declaration of Doug Snow (“Snow Decl.”)

¶¶ 3. As explained in more detail in SCE-5, filed on March 15, 2013 in I. 12-10-013,

SCE used a combination of actual, recorded costs, plus a forecast of the current year

capital costs to determine its estimated revenue requirements, which were then “trued-up”

in the subsequent year to reflect the actual, recorded costs as recorded in the SGRBA and

SGRDBA. Snow Decl. Ex. 1 (SCE-5 at 4-7). Because the ratemaking was set up to

recover only actual, recorded costs, no escalation or inflation factors were required or

used in determining either the estimated or the actual revenue requirements.

A4NR alleges that SCE misleadingly omitted mention of using an inflation

adjustment in reporting costs in three Advice Letters it used to seek interim inclusion of

certain SGRP costs in rates. Compl. ¶¶ 34-35. But SCE unambiguously did not use an

inflation adjustment in any of those Advice Letters; nor does A4NR allege any facts to

show that SCE did use an inflation adjustment. A4NR alleges only on information and

belief, and without alleging any basis for that belief, that it thinks SCE used an inflation

adjustment in these Advice Letters. Compl. ¶ 27.

In a portion of the SGRP Approval Decision not at issue in A4NR’s Complaint,

the Commission ordered that SCE was “authorized to recover through depreciation a total

of 20% of its ownership share ($22.2 million times its ownership share) of the estimated

removal and disposal costs for the original steam generators over 2006-2011.” D. 05-12-

040 at *46 (OP 12). These costs were not recorded in either of the balancing accounts

established through Advice Letter 2355-E. Advice Letter 2355-E at 3. As explained in

SCE-5, SCE recovered these costs through the filing of Advice Letters (1951-E, 2067-E,

2292-E, and 2402-E) separate from those mentioned in A4NR’s Complaint. Snow Decl.

Ex. 1 (SCE-5 at 2-3). SCE escalated the costs associated with this 20% of estimated

- 9 -

removal and disposal costs, and expressly referenced these inflation adjustments in the

Advice Letters. Id. at 3-4. Those Advice Letters were each approved and made effective

by the Commission’s Energy Division. Snow Decl. ¶ 4.

B. Procedural Background

On or about February 13, 2013, A4NR attempted to file a complaint before the

Commission (the “Original Complaint”), asserting five causes of action: (1) Violation of

Cal. Corp. Code § 25400(d) (California’s securities fraud statute); (2) Violation of 15

U.S.C. § 77q(a) and 15 U.S.C. § 78j(b) (federal securities fraud statutes); (3) Violation of

Cal. Gov. Code § 12650, et seq. (the California False Claims Act); (4) Violation of 31

U.S.C. § 3729 (federal False Claims Act); and (5) Violation of Cal. Bus. & Prof. Code

§ 17200, et seq. (California Unfair Competition Law (“UCL”)). In the Original

Complaint, A4NR requested that the Commission initiate a lawsuit pursuant to Cal. Pub.

Util. Code § 2101 “for the recovery of damages and punishment of the violations of law

alleged herein.” Orig. Compl. IV, ¶ 2.

On or about February 15, 2013, the Commission, in a letter from Karen V.

Clopton, Chief Administrative Law Judge (“ALJ”), advised A4NR that the Commission

would not accept A4NR’s Original Complaint for filing “because it seeks to adjudicate

claims which are not within the jurisdiction of this Commission.” Clopton Letter at 2.

On or about February 18, 2013, A4NR submitted for filing the instant amended

Complaint (hereinafter “Complaint”), which in no way revised the five causes of action

that the Commission advised were beyond its jurisdiction. Indeed, the amended

Complaint is almost identical to A4NR’s Original Complaint except in the following

significant respects: it inserts (1) an additional cause of action, alleging violation of Rule

1.1 of the Commission’s Rules of Practice and Procedure; (2) an additional item of

requested relief, that the Commission determine whether there is sufficient evidence to

warrant an “exercis[e] [of] its authority under Cal. Pub. Util. Code § 2101 or 2102 to

- 10 -

bring suit in the name of the People of the State of California” (Compl. at 2); and (3)

irrelevant allegations concerning Board of Review meeting minutes in which an inflation

adjustment was discussed. A redline showing the changes between A4NR’s original

complaint and the amended Complaint is attached to the Declaration of Henry

Weissmann (“Weissmann Decl.”) at Exhibit 1.

SCE met and conferred with A4NR to inform A4NR about the factual errors in its

Complaint. On February 20, 2013, counsel for SCE, Henry Weissmann of Munger,

Tolles & Olson LLP, spoke with counsel for A4NR, John L. Geesman of Dickson

Geesman LLP, by telephone. Weissmann Decl. ¶ 2. Mr. Weissmann explained to Mr.

Geesman that A4NR’s Complaint appeared to be premised on erroneous assumptions that

SCE had used inflation adjustments in reporting SGRP costs in the Relevant Advice

Letters, and a misinterpretation of statements in SCE’s and EIX’s securities filings. Mr.

Weissmann offered to provide Mr. Geesman with further factual information to assist

A4NR with assessing the merits of its Complaint. Id. Mr. Geesman responded that he

would advise Mr. Weissmann if he wished to continue a dialog about A4NR’s claims

after the docket office determined whether it would accept the Complaint for filing. Id.

On April 4, 2013, Mr. Weissmann again called Mr. Geesman and asked whether A4NR

intended to pursue its Complaint in light of SCE’s OII Testimony explaining that no

inflation adjustment was used in the Relevant Advice Letters. Id. at ¶ 3. Mr. Geesman

replied that the testimony left him with the impression that an inflation adjustment had

been used in those Advice Letters, although he declined to indicate what about the

testimony gave him that impression. Mr. Geesman stated that he intended to continue

pursuing the Complaint. Id.

On March 11, 2013, the Commission served SCE with the Complaint.

- 11 -

III. ARGUMENT

A. The Commission Lacks Jurisdiction Over The Majority Of Claims In The A4NR Complaint

1. The Commission Lacks Jurisdiction Over Claims Based On Violations Of Federal And State Law

Five of the six causes of action A4NR alleges—claims based on violations of

federal and state securities laws (first and second causes of action), federal and state false

claims statutes (fourth and fifth causes of action), and California’s UCL (sixth cause of

action)—are beyond the jurisdiction of this Commission. A4NR was already correctly

advised by Chief ALJ Clopton that the Commission had no jurisdiction over these five

causes of action. As the amended Complaint did not change in any substantive way these

five causes of action, ALJ Clopton’s conclusion is as correct with regards to the operative

Complaint as it was for the Original Complaint.

The Commission has jurisdiction to enforce the Public Utilities Code, not other

statutes. E.g., Greenlining Inst. v. PUC, 103 Cal. App. 4th 1324, 1328-32 (2002)

(holding that the Commission had no jurisdiction to adjudicate alleged violations of the

UCL); Goodspeed v. Great Western Power Co., 33 Cal. App. 2d 245, 273 (1939)

(holding that commission had no jurisdiction to hear claim concerning alleged fraud in

connection with stock sale); see also Motor Transit Co. v. Railroad Comm’n, 189 Cal.

573, 579-80 (1922) (explaining that Commission does not have the power to adjudicate

claims unrelated to the regulation of public utilities, like libel claims).

A4NR erroneously asserts that the Commission should entertain this Complaint

because it may “consider areas of law outside of its jurisdiction in fulfilling its duties.”

Compl. at 3. The Commission’s mandate is to supervise and regulate public utilities,

which it does through the enforcement of the Public Utilities Code. See Cal. Pub. Util.

Code § 701. The Commission may consider “law outside of [the Commission’s]

jurisdiction” only where necessary for the Commission to carry out its own mandate to

regulate and supervise utilities under the Public Utilities Code. E.g., Northern Cal.

- 12 -

Power Agency v. PUC, 5 Cal. 3d 370, 378 (1971) (holding that Commission’s

consideration of antitrust laws was permissible where such considerations would inform

the primary question of whether a proposed development was in the public interest).

Because no such nexus to the Commission’s authority under the Public Utilities Code is

alleged, the Commission lacks jurisdiction to adjudicate the statutory claims. See

Greenlining Inst., 103 Cal. App. 4th at 1331.

A4NR’s appeal to the doctrine of primary jurisdiction is also inapt. The primary

jurisdiction doctrine operates to stay an action in court that involves issues “within the

special competence of an administrative body,” and where initial agency review would

assist a court’s decisionmaking. Wise v. Pacific Gas & Elec. Co., 77 Cal. App. 4th 287,

295-96, (1999). In Greenlining, the California Court of Appeal specifically rejected the

argument that the primary jurisdiction doctrine conferred jurisdiction on the Commission

to adjudicate statutory claims not within the Commission’s power to adjudge. 103 Cal.

App. 4th at 1332 (dismissing argument that primary jurisdiction doctrine enabled

Commission to adjudicate UCL claims).

The Commission should dismiss all of A4NR’s statute-based claims.

2. The Commission Lacks Jurisdiction Over Claims Alleging Wrongdoing By Edison International

The Commission also should dismiss A4NR’s claims against Edison International

or its officers based on allegedly material false representations in certain of its securities

filings. Compl. ¶¶ 14, 15, 17, 29, 30, 33. This Commission lacks jurisdiction over EIX,

which is not a public utility subject to the Commission’s regulatory jurisdiction. The

Commission has been permitted to exercise jurisdiction over holding companies only

when such an extension of its jurisdiction is “cognate and germane to utility regulation.”

PG&E Corp. v. PUC, 118 Cal. App. 4th 1174, 1201 (2004) (emphasis in original)

(Commission has jurisdiction over holding companies to enforce conditions in

Commission decisions authorizing formation of holding companies). The evaluation of

- 13 -

EIX’s compliance with securities laws is not pertinent to this Commission’s regulation of

SCE and is beyond the Commission’s jurisdiction.

Moreover, enforcement of both federal and state securities fraud statutes is

reserved to the Securities and Exchange Commission (“SEC”), U.S. Department of

Justice, and California Department of Corporations. 15 U.S.C. § 78u(d) (authorizing

SEC to bring actions to enforce Section 10(b) of the Securities Exchange Act of 1934);

15 U.S.C. § 78ff(a) (codifying criminal penalties for violations of Securities Exchange

Act of 1934); 15 U.S.C. § 77t(b) (authorizing SEC to bring actions to enforce violations

of the Securities Exchange Act of 1933); California Amplifier, Inc. v. RLI Ins. Co., 94

Cal. App. 4th 102, 109 (“Enforcement of section 25400 is limited to administrative

proceedings initiated by the Department of Corporations.”) (citing Cal. Corp. Code

§§ 25530, 25532, 25535). The Commission has no jurisdiction to enforce these statutes,

which are far outside of the Commission’s mandate and expertise. Any attempt by the

Commission to enforce these securities fraud statutes against EIX would contravene the

securities statutes’ provisions that assign enforcement powers to other regulatory or

prosecutorial authorities. The Commission’s powers under Cal. Pub. Util. Code § 701

are circumscribed to the extent they contravene such “express legislative directives.”

Assembly v. PUC, 12 Cal. 4th 87, 103-04 (1995) (rejecting “a construction of section 701

that would confer upon the Commission powers contrary to other legislative directives”).

The Commission should dismiss A4NR’s claims to the extent they allege

wrongdoing or misrepresentations by EIX or any of its officers.

B. A4NR Has Failed To State A Claim For A Rule 1.1 Violation.

A4NR’s cause of action under Commission Rule 1.1 should be dismissed because

it fails to allege facts establishing a violation of that rule, and because the undisputed

facts show that there was no violation. See D. 99-11-023, 1999 WL 1957792, at *3 (Nov.

4, 1999) (complaint should be dismissed where, “taking the well-pleaded factual

allegations of the complaint as true, the defendant is entitled to prevail as a matter of

- 14 -

law”) (emphasis added); D. 12-03-037, 2012 WL 1135830 (Mar. 22, 2012); D. 13-01-

001, 2013 WL 265502, at § 3.1 (Jan. 10, 2013) (complaint should be dismissed “where

the evidence presented indicates there are no triable issues as to any material fact and

that, based on the undisputed facts, the moving party is entitled to judgment as a matter of

law”) (citing Cal. Code Civ. Proc. § 437(c)); see also D. 04-05-006, 2004 WL 1095245,

at *8 (May 26, 2005).

A4NR contends that SCE used “an inflation adjustment for the SGRP costs

addressed by its Advice Letters 2355-E, 2521-E, 2648-E-A, and 2834-E” (Compl. ¶ 34),

and misled the Commission and its staff by allegedly failing to disclose this alleged use

of an inflation adjustment (id. ¶ 35). A4NR’s Complaint includes no well-pled

allegations to support this claim. It alleges only on information and belief that SCE used

an inflation adjustment in calculating SGRP costs in those Advice Letters (id. ¶ 27)—but

states no basis for that belief. A4NR cites no document, testimony, or statement

indicating that SCE used such an inflation adjustment in calculating SGRP costs in those

Advice Letters. Moreover, as explained in SCE’s OII Testimony (SCE-5) and the

Declaration of Douglas Snow, filed concurrently herewith, SCE did not in any way use

any inflation adjustment in calculating SGRP costs reported in those Advice Letters.

Snow Decl. ¶ 3.4 Both A4NR’s inadequate pleading and the uncontroverted testimony of

Douglas Snow forecloses A4NR’s Rule 1.1 claim, and it must be dismissed.

C. A4NR Has Not Come Close To Alleging Violations Of The Federal And State Statutes It Asks The Commission To Enforce.

The Commission’s lack of jurisdiction over the statutory claims is dispositive, but

even if it were not, the statutory claims should be dismissed on the merits.

4 As noted, SCE did use an inflation adjustment in connection with the recovery of the 20% of estimated removal and disposal costs that are not at issue in the Complaint. SCE expressly disclosed the use of the inflation adjustment in the separate advice letters pursuant to which it recovered the estimated removal and disposal costs.

- 15 -

1. A4NR’s Securities Fraud Claims Fail.

A4NR does not even allege the most basic requirement of a securities fraud

action—that it purchased or sold securities, or sought to do so. Simply put, because there

are no securities at issue, A4NR has no securities fraud claim. In addition to this

fundamental flaw, each of A4NR’s securities claims is deficient for multiple reasons.

a. A4NR Has No Claim Based On 15 U.S.C. § 77q(a) (Section 17(a) Of The Securities Exchange Act Of 1933).

A4NR cannot bring a claim under 15 U.S.C. § 77q(a). That statute (also known

as Section 17(a) of the Securities Exchange Act of 1933), is generally raised in

enforcement actions brought by the SEC. A majority of circuits, including the Ninth

Circuit, agree that there is no private right of action under Section 17(a). E.g., In re

Wash. Pub. Power Supply Sys. Sec. Litig., 823 F.2d 1349, 1350-58 (9th Cir. 1987); Veltex

Corp. v. Matin, No. CV 10-1746 ABC (PJWx), 2010 WL 3834045, at *3 (C.D. Cal. Sept.

27, 2010); 4 THOMAS LEE HAZEN, THE LAW OF SECURITIES REGULATION § 12.22 (6th ed.

2009). Indeed, courts impose Rule 11 sanctions against plaintiffs or their counsel for

bringing private Section 17(a) claims where, as in the Ninth Circuit, existing authority

bars private plaintiffs from asserting Section 17(a) claims. Crookham v. Crookham, 914

F.2d 1027, 1028, 1029-30 (8th Cir. 1990) (sanctioning attorney for signing Section 17(a)

complaint); Fox v. Acadia State Bank, 937 F.2d 1566, 1570 (11th Cir. 1991) (affirming

grant of sanctions for maintaining Section 17(a) claim).

b. A4NR Fails To Allege Multiple Required Elements Of A Claim Under 15 U.S.C. § 78j(b) (Section 10(b) Of The Securities Exchange Act Of 1934).

A4NR also fails to state a claim for a violation of 15 U.S.C. § 78j(b) (also known

as Section 10(b)). As noted above, the most basic element of a securities claim—the

purchase or sale of a security—appears nowhere in A4NR’s Complaint. 15 U.S.C.

§ 78j(b); 17 C.F.R. § 240.10b-k (2000) (regulation implementing Section 10(b), also

known as Rule 10b-5); Blue Chip Stamps v. Manor Drug Stores, 421 U.S. 723, 731, 749

- 16 -

(1975) (holding that to bring a Rule 10(b) claim, plaintiffs must have purchased or sold

securities at issue). A4NR thus lacks standing to bring its Section 10(b) claim. See, e.g.,

Ontario Pub. Serv. Employees Union Pension Trust Fund v. Nortel Networks Corp., 369

F.3d 27, 32-33 (2d Cir. 2004) (affirming dismissal for lack of standing where plaintiffs

did not purchase securities of corporation alleged to have made misrepresentations).

In addition, A4NR fails to allege any of the required elements of a Section 10(b)

claim: that a defendant (1) made a false statement or an omission of material fact, (2)

with scienter, (3) in connection with the purchase or sale of a security, (4) upon which the

plaintiff justifiably relied, and (5) which proximately caused (6) the plaintiff’s economic

loss. See, e.g., Dura Pharm., Inc. v. Broudo, 544 U.S. 336, 341 (2005). Rule 10(b)

claims are subject to the heightened pleading requirements of Rule 9(b) and the Private

Securities Litigation Reform Act (“PSLRA”). Desaigoudar v. Meyercord, 223 F.3d

1020, 1022-23 (9th Cir. 2000).

No false statement: A Section 10(b) plaintiff must plead falsity with particularity.5

Rubke v. Capitol Bancorp Ltd., 551 F.3d 1156, 1164 (9th Cir. 2009). But A4NR’s

Complaint fails to demonstrate that SCE or EIX made any false statement whatsoever.

Instead, A4NR lends implausible constructions to isolated phrases it plucks out of SCE

and EIX securities filings and an earnings conference call. This kind of unwarranted

distortion of statements is insufficient to allege falsity. As courts have repeatedly found,

falsity cannot be alleged based on a mere misinterpretation of a statement. See, e.g.,

Rubke, 551 F.3d at 1164-65 (affirming grant of motion to dismiss Rule 10(b) claim where

allegations of misleading statement “simply misconstrue[d] the language” of a

registration statement); In re Coinstar Inc. Sec. Litig., No. C11-133 MJP, 2011 WL

5 If the Commission does consider the merits of A4NR’s claims, it should apply the same pleading standards that courts have consistently required for plaintiffs bringing the same claims in civil court.

- 17 -

4712206, at *7 (W.D. Wash. Oct. 6, 2011) (finding statements not adequately pled as

false where plaintiff “interpret[ed] [defendant’s] statements out of context”).

The Complaint points to two allegedly misleading statements. First, A4NR

highlights a sentence in SCE and EIX’s 10-K and 10-Q submissions stating, “In 2005, the

CPUC authorized expenditures of approximately $525 million ($665 million when

adjusted for inflation) for SCE’s 78.21% share of San Onofre to purchase and install” the

new steam generators and remove and dispose of their predecessors. Compl. ¶¶ 15, 17.

A4NR contends that this statement is untrue because there was no “‘authorized’ inflation-

adjusted amount” for the costs of the SGRP, and because the Commission has not yet

authorized “a particular adjustment for inflation.” Id. ¶¶ 15, 19. But the submissions do

not state that the Commission authorized any particular adjustment for inflation. Instead,

they state (1) that the Commission authorized expenditures of $525 million, and (2) that

the $525 million, when adjusted for inflation, translates to $665 million. The second

statement is set off in parentheses, and the word “authorized” at the beginning of

statement (1) does not modify the verb “adjusted” in statement (2). Compl. ¶¶ 15

(quoting EIX 10-K, dated Feb. 29, 2012), 16 (citing SCE 10-K, dated Feb. 29, 2012), 17

(quoting EIX and SCE 10-Qs, dated May 2, 2012, July 31, 2012, Nov. 1, 2012). Only by

ignoring the plain structure of the sentence can A4NR make out an alleged

misrepresentation.

Second, the Complaint focuses Mr. Craver’s statement comparing SCE’s

expenditures on the SGRP “to the inflation-adjusted authorized spend of $665 million.”

Compl. ¶ 14. A4NR contends that Mr. Craver’s statement must be read to mean

“authorized inflation-adjusted spend,” and thus that Mr. Craver indicated that an inflation

adjustment had been authorized by the Commission. A4NR’s interpretation depends on

changing the order of Mr. Craver’s words. In Mr. Craver’s statement, the word

“authorized” modifies “spend,” not “inflation-adjusted.” He did not say that the

Commission authorized an inflation adjustment.

- 18 -

No materiality: To be actionable, the alleged misrepresentation under Section

10(b) must not only be false but material—i.e., there must be a substantial likelihood that

a reasonable investor would consider the statement important in making a decision

because it would significantly alter the “total mix” of available information. TSC Indus.,

Inc. v. Northway, Inc., 426 U.S. 438, 449 (1976). The PSLRA’s heightened pleading

requirement applies to the materiality as well. In re Cutera Sec. Litig., 610 F.3d 1103,

1108-09 (9th Cir. 2010) (“‘[C]onclusory allegations of law and unwarranted inferences

are insufficient to defeat a motion to dismiss for failure to state a claim.’”) (quoting

Halkin v. VeriFone Inc. (In re VeriFone Sec. Litig.), 11 F.3d 865, 868 (9th Cir. 1993)).

“‘[A] statement is misleading if it would give a reasonable investor the impression of a

state of affairs that differs in a material way from the one that actually exists.’” In re

Cutera, 610 F.3d at 1109 (quoting Berson v. Applied Signal Tech., Inc., 527 F.3d 982,

985 (9th Cir.2008)). Further, alleged misrepresentations or omissions are not materially

misleading if the information is already in the public domain and available to investors.

United Paperworkers Int’l Union v. Int’l Paper Co., 985 F.2d 1190, 1199 (2d Cir. 1993).

A4NR does not come close to adequately alleging the materiality of the alleged

falsehoods here. Indeed, the Complaint does not even attempt to explain how the

difference between an “inflation-adjusted authorized spend” and an “authorized inflation-

adjusted spend” would be material to any hypothetical investor (hypothetical because

A4NR does not allege that there was any investor damaged by the alleged

misrepresentations). A4NR does not contend that this would have caused an investor to

purchase stock when she otherwise would not have, or purchase stock at a higher price,

or make any investing decision at all in light of the statements. Moreover, to the extent

any investor cared about whether there had been a particular inflation adjustment

authorized for the SGRP costs, the Commission’s SGRP Approval Decision was publicly

available at the time of the alleged misrepresentations. Any investor could have reviewed

the decision and understood that the Commission had not authorized an inflation

- 19 -

adjustment for purposes of determining whether SCE had stayed within the reasonable

cost threshold (as well as that the Commission contemplated that an inflation adjustment

of some sort would be appropriate). Indeed, the Complaint does not even attempt to

allege that the supposed misrepresentations affected the price of EIX or SCE securities in

any way. The alleged misrepresentations here simply did not change, in any way, the

“total mix” of information available to the public and the investing community.

No scienter: “Under the PSLRA’s heightened pleading instructions, any private

securities complaint alleging that the defendant made a false or misleading statement

must: . . . state with particularity facts giving rise to a strong inference that the defendant

acted with the required state of mind.” Tellabs, Inc. v. Makor Issues & Rights, Ltd., 551

U.S. 308, 321 (2007) (citations omitted). A plaintiff must plead in “great detail” facts

providing “strong circumstantial evidence of deliberately reckless or conscious

misconduct”; this requires more than “mere recklessness.” In re Silicon Graphics Sec.

Litig., 183 F.3d 970, 974 (9th Cir. 1999); WPP Luxembourg Gamma Three Sarl v. Spot

Runner, Inc., 655 F.3d 1039, 1055 (9th Cir. 2011) (affirming dismissal where “strong

inference” standard not met and one plausible explanation for defendant’s statement was

confusion about investor’s question); Ronconi v. Larkin, 253 F.3d 423, 429 (9th Cir.

2001) (granting motion to dismiss because complaint lacked allegations sufficient to raise

a strong inference of required scienter). The inference of intent “must be more than

merely plausible or reasonable—it must be cogent and at least as compelling as any

opposing inference of nonfraudulent intent.” Tellabs, 551 U.S. at 309. A4NR’s

Complaint includes no allegations to show that SCE or EIX personnel made misleading

statements intentionally or with recklessness. No facts are alleged that would tend to

show that SCE or EIX had the fraudulent intent of causing investors to believe that the

Commission had authorized a particular inflation adjustment for the SGRP costs. Such

an inference is not even reasonable, much less strong.

- 20 -

No purchase or sale of security, so no reliance, causation, or loss: Because no

purchase of a security or any investing decision whatsoever is alleged here, A4NR cannot

contend that it (or anyone else) relied on the statements it alleges were false or

incomplete. Nor are there any allegations to support the required element that A4NR (or

anyone else) suffered any losses because of the alleged misrepresentations, or that those

losses could have been caused by those alleged misrepresentations.

c. A4NR’s Complaint Has Not Stated A Claim For A Violation Of Cal. Corp. Code § 25400(d).

For similar reasons to those that foreclose A4NR’s Section 10(b) claim, A4NR’s

claim under California’s securities statutes also fails. A plaintiff asserting a Section

25400(d) claim must demonstrate that: (1) “a person selling or offering for sale . . . the

security” has made, (2) “for the purpose of inducing the purchase” of a security by

others,” (3) “any statement which was, at the time and in the light of the circumstances

under which it was made, false or misleading with respect to any material fact, or which

omitted to state any material fact necessary in order to make the statements made, in the

light of the circumstances under which they were made, not misleading,” (4) “which he

knew or had reasonable ground to believe was so false or misleading”; and which

affected the price of a security, damaging a purchaser. Cal. Corp. Code §§ 25400(d),

25500. A4NR’s Complaint fails to allege facts sufficient to satisfy any of the required

elements of this Section 25400(d) claim:

No intent to induce purchase of security: The Complaint does not allege any facts

from which one could infer that any SCE or EIX representative made statements “for the

purpose of inducing the purchase or sale of” a security by another person (Cal. Corp.

Code § 25400(d))—e.g., with the “specific intent to affect the price of a security in order

to induce its purchase or sale.” California Amplifier, Inc., 94 Cal. App. 4th at 110 (citing

Cel-Tech Commc’ns., Inc. v. Los Angeles Cellular Tel. Co., 20 Cal. 4th 163, 173 (1999))

(emphasis added).

- 21 -

No misrepresentation or omission of material fact: As explained above, neither

SCE nor EIX made any actionable misrepresentation or omission whatsoever, much less

one concerning a “material fact.” This materiality standard is the same under Cal. Corp.

Code § 25400(d) as it is under federal securities statutes; thus, the analysis showing that

the materiality standard was not met with respect to A4NR’s Section 10(b) claim also

forecloses A4NR’s Section 25400(d) claim. 1 HAROLD MARSH, JR. & ROBERT H. VOLK,

PRACTICE UNDER CALIF. SEC. LAWS 14.05[2][e] (rev. ed. 2012).

No scienter: Under Section 25400(d), the “required level of culpability . . . is the

equivalent of recklessness.” California Amplifier, 94 Cal. App. 4th at 109. “In the

context of securities fraud, recklessness exists when the danger of misleading buyers or

sellers is so obvious that the defendant must have been aware of it.” Id. at 110 (citing

Hollinger v. Titan Capital Corp., 914 F.2d 1564, 1569 (9th Cir. 1990)). Here, there are

no allegations that there was any danger of misleading buyers or sellers whatsoever,

much less that that danger was so “obvious” that SCE or EIX would have been aware of

it. Nor is there any allegation that any SCE or EIX person was aware of any such risk or

made the statement with such awareness.

No impact on price of security. “In order to recover [a plaintiff] must, of course,

establish that the price paid or received was affected by the defendant’s wrongful

conduct.” 1 MARSH & VOLK § 14.05[5]. Having failed to make this allegation, A4NR

has no claim under Section 25400(d). Nor has A4NR alleged that the price of any

security was affected by any SCE or EIX statement.

2. A4NR’s False Claims Act Claims Also Fail.

A4NR contends that it does not seek to be a qui tam plaintiff or relator. Compl.

¶¶ 40, 43. But this ploy does not enable A4NR to skirt the procedural requirements with

which qui tam plaintiffs must comply. A4NR, like other private actors filing suit under

the federal and California False Claims Acts, was required to first file its complaint in

- 22 -

court and under seal. 31 U.S.C. § 3730(b)(2); Cal. Gov. Code § 12652(c)(2). Relators

under either statute must also serve the federal government or the California Attorney

General with a copy of the complaint along with “written disclosure of substantially all

material evidence and information the person possesses.” 31 U.S.C. § 3730(b)(2); Cal.

Gov. Code § 12652(c)(3). A4NR has failed to comply with either of these requirements.6

In addition, A4NR has failed to state a claim under either False Claims Act. “The

essential elements of False Claims Act liability [are]: (1) a false statement or fraudulent

course of conduct, (2) made with scienter, (3) that was material, causing (4) the

government to pay out money or forfeit moneys due.” United States ex rel. Hendow v.

Univ. of Phoenix, 461 F.3d 1166, 1174 (9th Cir. 2006).7

Failure to identify false claim: To state a claim under either the federal or

California False Claims Act, a plaintiff must plead its claims with the particularity. E.g.,

Bly-Magee v. California, 236 F.3d 1014, 1018 (9th Cir. 2001) (holding that Fed. R. Civ.

Proc. 9(b) pleading requirements applied to federal False Claims Act (“FFCA”) claim);

State ex rel. McCann v. Bank of America, N.A., 191 Cal. App. 4th 897, 906 (2011)

(California False Claims Act (“CFCA”) claims must be pleaded with particularity).

Thus, a False Claims Act plaintiff must, “at a minimum, plead the ‘who, when, where and

6 As discussed below, A4NR’s false claims allegations are so vague and uncertain that it is impossible for SCE to determine exactly what submittals are alleged to be “false” and what about them are alleged to be “false.” From A4NR’s existing allegations, it appears that an additional jurisdictional bar applies to its claims: the “public disclosure” bar codified in both the federal and California False Claims Acts. See 31 U.S.C. § 3730(e)(4)(A); Cal. Gov. Code § 12652(d)(1)-(4). The “public disclosure” bar, which precludes claims based on allegations already in the public domain, also likely bars A4NR’s claims. Indeed, A4NR admits that “[t]he information upon which this complaint is based is in the public domain.” Compl. ¶¶ 40, 43; see United States ex rel. Longstaffe v. Litton Indus., Inc., 296 F. Supp. 2d 1187, 1195 (C.D. Cal. 2003) (dismissing qui tam action where “publicly disclosed allegations were sufficient to put the government on notice of the alleged FCA violations”); State ex rel. Grayson v. Pac. Bell Tel. Co., 142 Cal. App. 4th 741, 748 (2006) (citing federal False Claims Act, 31 U.S.C. § 3729, et seq.) (barring qui tam claim where allegation had been publicly disclosed in trade journals). 7 Because the California False Claims Act “‘was modeled on the federal False Claims Act, . . . it is appropriate to turn to federal cases for guidance in interpreting the [CFCA].’” Mao’s Kitchen, Inc. v. Mundy, 209 Cal. App. 4th 132, 146 (2012) (alteration in original) (citations omitted).

- 23 -

how’ as well as the specific content of each alleged act of fraud to allow the defendant to

defend against the charge and not just deny that it has done anything wrong.” United

States ex rel. UNITE HERE v. Cintas Corp., No. C 06-2413 PJH, 2008 WL 1767039, at

*5 (N.D. Cal. Apr. 16, 2008) (citing Bly-Magee, 236 F.3d at 1018-19) (granting motion

to dismiss for failure to plead FFCA claim with particularity).

A4NR’s False Claim Acts causes of action do not come close to meeting this

standard. In its Fourth and Fifth Causes of Action, A4NR fails even to identify what

“billings” it contends were falsely made. E.g., County of Santa Clara v. Astra United

States, Inc., 428 F. Supp. 2d 1029, 1037 (“plaintiff’s failure to allege with any specificity

if—or when—any actual improper claims were submitted is fatal”). Indeed, A4NR does

not even allege that there were any false “billings,” basing its False Claims Act claims on

possible billings “[t]o the extent that Defendant SCE’s 2011 and 2012 rates and charges

included any inflation adjustment . . . .” Compl. ¶¶ 37, 38, 41 (emphasis added).

Moreover, A4NR has failed to identify exactly what species of false claim it alleges SCE

committed, or under which of the various false claims statutory provisions A4NR sues.

See, e.g., 31 U.S.C. § 3729(a)(1)(A) (presenting false claim); 31 U.S.C. § 3729(a)(1)(D)

(wrongful possession of government property); 31 U.S.C. § 3729(a)(1)(F) (false receipt);

Cal. Gov. Code § 12651(a)(1) (presenting false claim); Cal. Gov. Code § 12651(a)(6)

(wrongful possession of public property); Cal. Gov. Code § 12651(a)(8) (beneficiary of

inadvertent submission of false claim).

No falsity: “At a minimum, the [False Claims Act] requires proof of an objective

falsehood.” Fru-Con Const. Corp. v. Sacramento Mun. Utility Dist., No. CIV. S-05-583

LKK/GGH, 2007 WL 1791699, at *19 (E.D. Cal. June 15, 2007) (quoting United States

ex rel. Roby v. Boeing Co., 100 F. Supp. 2d 619, 625 (S.D. Ohio 2000)). As A4NR does

not even identify what submittal it claims was falsely made, A4NR has not alleged that

supposed submittal’s falsity.

- 24 -

Even assuming that A4NR intended to allege that the Relevant Advice Letters

constituted false claims, A4NR does not properly allege that the Advice Letters are false

in any way. A4NR alleges that the Advice Letters do not state that any inflation

adjustment was used, but contends only on “information and belief” that an inflation

adjustment was used. “Allegations of fraud based on information and belief do not

satisfy the particularity requirement unless accompanied by a statement of the specific

facts on which the belief is founded.” County of Santa Clara, 428 F. Supp. 2d at 1036

(granting motion to dismiss CFCA claim for failure to plead with particularity). A4NR

proffers no allegations suggesting or showing that any inflation adjustment was actually

used in the Advice Letters. Thus, A4NR has failed to allege the falsity of the statements

in the Advice Letters. See, e.g., United States v. Dan Caputo Co., 321 F.3d 926, 933 (9th

Cir. 2003) (“For a false claim suit to succeed, the plaintiff must show that the claim was

false, that is, contrary to an existing state of things.”).

Finally, any alleged falsity in the Advice Letters does not establish that the bills

remitted to government customers are false. Those bills set forth charges based on rates

computed in accordance with tariffs on file with the Commission. Whether those rates

were computed correctly or not—and, as shown above, they were computed correctly—

the charges on the bills were not false.

No materiality: Because A4NR has not alleged that a false claim was even made,

it has also failed to plead materiality with particularity. E.g., United States ex rel.

Herndon v. Science Applications Int’l Co., No. 05CV2269-BEN, 2007 WL 2019653 at *5

(S.D. Cal. July 10, 2007) (dismissing complaint where allegations not sufficient to show

materiality). Because no particular claim is at issue, it is impossible for A4NR to contend

that any statement in any such claim would have been material to a government official

reviewing the claim.

- 25 -

No causation of government pay out: A4NR’s complaint includes no allegations

that any government entity paid out money based on false submittals (that A4NR does

not identify). A4NR thus fails to allege this essential element as well.

3. A4NR Has Failed To State A Claim Under California’s Unfair Competition Law.

A4NR’s Sixth Cause of Action asserts that SCE has engaged in “unlawful,

fraudulent, or unfair acts or practices” under the UCL, which acts or practices consist of

violations of the five statutes and rules which A4NR contends SCE has violated in its

other five causes of action. Compl. ¶ 44. Thus, A4NR appears to allege a violation of

the “unlawful” prong of the UCL.

Regardless of what prong A4NR attempts to sue under, A4NR’s claim would fail

because it lacks standing to bring a UCL claim. A plaintiff has standing to sue under the

UCL “only if he or she ‘has suffered injury in fact and has lost money or property as a

result of such unfair competition’ (§ 17204, as amended by Prop. 64, § 3; see also §

17203, as amended by Prop. 64, § 2.).” Californians for Disability Rights v. Mervyn’s,

LLC, 39 Cal. 4th 223, 227 (2006); Kwikset Corp. v. Superior Court, 51 Cal. 4th 310, 322

(2011) (“To satisfy the narrower standing requirements imposed by Proposition 64, a

party must now (1) establish a loss or deprivation of money or property sufficient to

qualify as injury in fact, i.e., economic injury, and (2) show that that economic injury was

the result of, i.e., caused by, the unfair business practice . . . that is the gravamen of the

claim.”) (emphasis in original). A4NR does not allege facts sufficient to show that it

meets this essential requirement.

A4NR cannot state a claim under the UCL’s “unlawfulness” prong in any event

because it cannot establish that SCE or EIX engaged in any “unlawful” conduct. A claim

based on the unlawfulness prong of the UCL “‘borrows’ violations of other laws” and

treats such violations as independently actionable under the UCL. Farmers Ins.

Exchange v. Superior Court, 2 Cal. 4th 377, 383 (1992); see also Chabner v. United of

- 26 -

Omaha Life Ins. Co., 225 F.3d 1042, 1048 (9th Cir. 2000). Absent violation of another

law, A4NR’s unlawfulness claim under the UCL fails. As demonstrated above, A4NR

has not come close to stating a claim for any of the statutes or rules that A4NR contends

serve as a predicate for its UCL “unlawfulness” claim.

D. The Commission Should Not Initiate A Lawsuit Based On A4NR’s Complaint.

In its Prayer for Relief, A4NR asks this Commission to determine whether it

should initiate suit pursuant to its authority under Cal. Pub. Util. Code §§ 2101 or 2102.

Compl. § IV, ¶¶ 2-3. The Commission should reject out of hand this improper attempt to

skirt the pleading and other requirements to which A4NR would have been subject had it

filed in a court of proper jurisdiction.

A4NR’s request that the Commission itself bring suit is ill-founded, as the

Commission lacks that jurisdictional power entirely.8 Moreover, as there is no

substantive basis for any of A4NR’s claims, A4NR’s suggestion that the Commission

attempt to convince federal or state prosecutors to file a complaint to prosecute these

claims against SCE or EIX is nonsensical. The multiple, fundamental deficiencies of

A4NR’s contentions and the counterfactual assumptions that underlie them show A4NR’s

claims to be meritless, no matter who asserts them.

E. The Complaint Is An Improper Attempt To Circumvent The OII.

A4NR’s Complaint raises issues that the Commission already has a process for

addressing. SCE has already submitted testimony in A. 13-03-005 that explains how it

8 The Commission has no power to bring any of the five statute-based claims on behalf of the People of California. As discussed above, the enforcement of securities action are reserved to other government entities like the SEC. 15 U.S.C. § 78u(d); 15 U.S.C. § 78ff(a); 15 U.S.C. § 77t(b); California Amplifier, 94 Cal. App. 4th at 109. Non-qui tam False Claims Act actions must be brought either by the Commission’s “prosecuting authority” (Cal. Gov. Code § 12652(b)(1)), or the United States Attorney General (31 U.S.C. § 3730(a)). The California Attorney General, district attorneys, and others “expressly are authorized to bring UCL claims in court, but [] the PUC is not.” People ex rel. Orloff v. Pac. Bell, 31 Cal. 4th 1132, 1153 (2003) (citing Cal. Bus. & Prof. Code §§ 17204, 17535).

- 27 -

computed the interim revenue requirement, and the Commission will review that

testimony in I. 12-10-013. The Complaint is a wholly unnecessary distraction from the

existing proceedings, and a wholly improper attempt to circumvent the procedural

schedule set forth in the Scoping Memo in the OII.

More broadly, A4NR’s Complaint is frivolous. Each of A4NR’s causes of action

fail for multiple, fundamental reasons—some of which require minimal legal research to

identify. It would take little to no effort to determine, for example, that a securities fraud

claim requires that the purchase, sale, or offer to sell a security be at issue, or that a False

Claims Act claim requires a false claim to be identified, or that some injury is required to

state a UCL violation. Yet A4NR did not even try to allege facts for most of the

necessary elements for any of its statutory claims. Nor do any of A4NR’s claims have

any evidentiary basis.

Indeed, A4NR’s decision to proceed with this Complaint evinces a lack of good

faith. The Commission already advised A4NR that its statute-based causes of action are

beyond the Commission’s jurisdiction to adjudicate and cannot be asserted in this venue.

Yet in filing its Amended Complaint, A4NR did not delete any of those causes of action.

Further, because A4NR’s claims are founded on an apparent confusion about SCE’s

SGRP-related filings and this Commission’s SGRP-related decisions, SCE’s counsel

twice attempted to meet and confer with A4NR about its complaint. Yet A4NR rebuffed

SCE’s invitation for further explanation and has persisted with its Complaint even though

its counsel not been able to explain why it believes the baseless assumptions upon which

its Complaint is based in light of SCE’s OII testimony. As a result, even though all of

A4NR’s claims are entirely meritless, SCE has had to conduct extensive research and

expend hours of effort to prepare and file responsive papers, and the Commission will

have to expend its limited resources resolving the Complaint. In these circumstances, the

- 28 -

Commission may wish to consider whether it would be appropriate to impose sanctions

on A4NR in connection with the Complaint.9

IV. CONCLUSION

The Commission should dismiss A4NR’s Complaint.

Respectfully Submitted, DOUGLAS K. PORTER WALKER A. MATTHEWS RUSSELL A. ARCHER HENRY WEISSMANN JONATHAN E. ALTMAN JOHN B. OWENS LIKA C. MIYAKE /s/ Walker A. Matthews_______________________ By: Walker A. Matthews Attorneys for SOUTHERN CALIFORNIA EDISON COMPANY 2244 Walnut Grove Avenue Post Office Box 800 Rosemead, California 91770 Telephone: (626) 302-6879 Facsimile: (626) 302-3990 E-mail: [email protected]

Date: April 10, 2013

9 See Commission Rule 1.8(f), 1.8(b) (authorizing sanctions for willful violation of requirement that, inter alia, legal contentions in documents filed before the Commission “are warranted by existing law” and facts are true based on a “reasonable inquiry”). Courts have sanctioned parties and counsel for bringing exactly the kind of frivolous claims A4NR asserts here. Crookham, 914 F.2d at 1028 (sanctioning attorney for signing Section 17(a) complaint); Fox, 937 F.2d at 1570 (affirming grant of sanctions for maintaining Section 17(a) claim); County of Kern v. Jadwin, 197 Cal. App. 4th 65, 72 (2011) (affirming grant of attorneys’ fees sanctions for harassing filing and pursuit of California False Claims Act claim).

Declaration of Douglas Snow

Exhibit 1

SCE’s Testimony in Response to February 21, 2013 Ruling

Application No.: I.12-10-013 Exhibit No.: SCE-5 Witnesses: D. Snow J. Perez

(U 338-E)

SCE’s Testimony In Response to February 21, 2013 Ruling

Before the

Public Utilities Commission of the State of California

Rosemead, CaliforniaMarch 15, 2013

SCE’s Testimony In Response to February 21, 2013 Ruling

Table Of Contents Section Page Witness

-i-

I.� INTRODUCTION .............................................................................................1 D. Snow/J. Perez�

II.� RATEMAKING .................................................................................................2 D. Snow�

A.� SGRP RATEMAKING ..........................................................................2�

1.� Recovery of 20% of the Removal and Disposal Costs ...........................................................................................2�

2.� Implementation of Provisional SGRP Ratemaking ...................4�

B.� Recorded SGRP Revenue Requirements ...............................................6�

C.� Calculation Of The SGRP Revenue Requirements ...............................7�

1.� Depreciation Expense ................................................................8�

2.� Property Taxes ...........................................................................8�

3.� Federal and State Income Taxes ................................................9�

4.� Return on Rate Base...................................................................9�

III.� SGRP EXPENSES ...........................................................................................10 J. Perez�

IV.� CONCLUSION ................................................................................................12 D. Snow/J. Perez�

Appendix A Witness Qualifications ............................................................................13�

Appendix B ....................................................................................................................5�

Appendix C ....................................................................................................................6�

Appendix D ....................................................................................................................7�

Appendix E ....................................................................................................................8�

1

I.1

INTRODUCTION2

This testimony addresses Question Nos. 1-3 posed in the Administrative Law Judge’s (ALJ) 3

February 21, 2013 ruling: 4

51. For the following Advice Letters submitted by SCE, as 6

permitted by D.05-12-040, to implement interim revenue requirements for 7recovery of costs related to replacement of the steam generators at 8SONGS units 2 and 3, clearly explain how SCE calculated the requested 9revenue requirement: 10

� Advice 2521-E dated November 1, 2010; 11� Advice 2648-E dated December 27, 2011; and 12� Advice 2834-E dated December 31, 2012. 13

2. Identify the rates of depreciation and service life assumptions 14applied to the various components which form the basis for the revenue 15requirement requests identified in number 1 above. 16

3. For all expenses in excess of $1 million, identify each SGRP 17expense categorized as “Investigation” and “Repairs-After Outage” 18aggregated in SCE’s monthly report ($67.06 million and $27.3 million, 19respectively) submitted on February 1, 2013. 20

Section II responds to Question Nos. 1-2 and explains the manner in which rates have been 21

established to date to recover costs associated with the Steam Generator Replacement Program 22

(“SGRP”). SCE is filing on March 15, 2013 an application for inclusion of the SGRP costs permanently 23

in rates. Section III responds to Question No. 3 and provides further details regarding SGRP expenses 24

reported in SCE’s February 1, 2013 monthly report.25

2

II.1

RATEMAKING 2

A. SGRP RATEMAKING 3

The Commission in D.05-12-040 authorized SCE to implement ratemaking such that SCE could 4

1) recover a limited amount of the removal and disposal costs prior to the completion of the SGRP over 5

the six year period of 2006 through 2011; 2) begin to provisionally recover its SGRP revenue 6

requirement associated with the steam generator replacement costs for each generating unit, subject to 7

refund, the year following commercial operation of each generating unit; and 3) continue to 8

provisionally recover the removal and disposal costs, subject to refund, the year following when the 9

work to remove and dispose of the original generating units was complete. Each of these ratemaking 10

elements is discussed in further detail below in subsections 1-3. 11

1. Recovery of 20% of the Removal and Disposal Costs 12

Ordering Paragraph (OP) No. 12 of D.05-12-040 states that “SCE is authorized to recover 13

through depreciation a total of 20% of its ownership share ($22.2 million [(2004$) multiplied] by its 14

ownership share) of the estimated removal and disposal costs for the original generators over 2006-15

2011.” 1 As shown on Line No. 8 of Table II-1 below, SCE’s share of the $22.2 million is $17.25 16

million (2004$). SCE recovered the $17.25 million in equal annual portions over the six year period 17

2006 through 2011 pursuant to OP 12.2 Each year beginning in 2005, SCE filed an advice letter and 18

provided the amount that would be recovered in rates for the subsequent year.19

1 As explained in footnote No. 2 of D.05-12-040, all dollar figures included in the decision are stated as 2004 dollars unless otherwise specified.

2 The amount recovered in 2006 was slightly different due to a different ownership share before SCE acquired Anaheim’s share of SONGS 2&3.

3

Table II-1 Recovery of Estimated 20% of Removal and Disposal Costs

Revenue Requirement ($millions)

1.0687� 1.1150� 1.2118� 1.2640� 1.2559� 1.3260�

1.1556� 1.2423� 1.3355� 1.4356� 1.5433�

1.5351� 1.6415�

Advice�1951�E

Advice�2067�E

Advice�2067�E

Advice�2292�E

Advice�2402�E

Advice�2402�E

Totals�2006�2011

2004$ 2006 2007 2008 2009 2010 20111 111.2��

2 22.2��

3 75.05%

4 78.21%

516.66��

617.36��

72.78�� 2.78��

82.89�� 2.89�� 2.89�� 2.89�� 2.89�� 2.89�� 17.25��

9 75.3% 0.14�� 0.25�� 0.46�� 0.58�� 0.56�� 0.71��10 24.7% 0.11�� 0.17�� 0.24�� 0.31�� 0.38�� 0.46��11 0.25�� 0.42�� 0.70�� 0.89�� 0.94�� 1.17�� 4.37��

12 3.03�� 3.32�� 3.60�� 3.78�� 3.84�� 4.06�� 21.62��

13 3.06�� 3.36�� 3.64�� 3.83�� 3.88�� 4.11�� 21.87��

SCE's �Ownership�Share�(wi thout�City�of�Anaheim)

Non�Buria l �Esca lation�Rate��1/

7.5%�Buria l �Esca lation�Rate�(D.03�10�015�and�D.07�0

6.93%�Buria l �Esca lation�Rate�(D.10�07�047)��2/

(Authorized)

SGRP�Removal �and�Disposa l �Costs

Authorized�Recovery�of�20%

SCE's �Ownership�Share�(wi th�Ci ty�of�Anaheim)

Tota l �Nominal �Removal �and�Disposa l �Costs �to�be�recorded�in�BRRBA��3/

SCE's �Share�of�Removal �&�Disposa l �Costs �(wi th�Anaheim)��2006

SCE's �Share�of�Removal �&�Disposa l �Costs �(wi thout�Anaheim)��2007�2011

Amount�annual ly�in�rate�levels �from�2006�(wi th�Anaheim)�2004$

Amount�annual ly�in�rate�levels �from�2007�2011�(wi thout�Anaheim)�2004$

Removal �Costs ��Non�Buria l �Esca lation�Rate

Disposa l �Costs ��Buria l �Esca lation�Rate�

Total�Escalation

3/�Base�Revenue�Requirement�Ba lancing�Account�(BRRBA)�Without�Franchise�Fees �&�Uncol lectibles �(FF&U).�Line�7�+�Line�11�(2006),�Line�8�+�Line�11�(2007�2011).��SCE's �ownership�changed�when�i t�purchased�Anahaeim's �share�of�SONGS.

4/��Line�12�BRRBA�amounts �x�GRC�authorized�FF&U�factors �for�each�year�2006�to�2011.

Total�Nominal�Removal�and�Disposal�Costs�in�rate�levels�with�FF&U��4/

2/�7.5%�esca lation�rate�agreed�to�in�settlement�adopted�in�D.03�10�015�and�confirmed�in�D.07�01�003.�The�Commiss ion�authorized�a �mean�buria l �esca lation�estimate�of�6.93%�effective�May�1,�2010.�The�7.5%�buria l �escation�rate�i s �authorized�for�Jan.�1,�through�Apr.�30,�2010�and�the�6.93%�buria l �esca lation�rate�i s �authorized�for�May�1,�2010�through�Dec.�31,�2011.

1/�Handy�Whitman�Construction�index�from�Global �Ins ight�projection.

In each annual determination of the amount to be included in rates, SCE added escalation 1

to the annual amount in order to recover a nominal amount of removal and disposal depreciation each 2

year. The escalation amount included each year is shown on Line Nos. 9 through 11 of Table II-1. The 3

escalation rates included two components. First, non-burial costs were escalated using the Handy 4

4

Whitman Construction Index. Second, burial costs were escalated using the 7.5% and 6.93% escalation 1

rate approved by the Commission in the Nuclear Decommissioning Costs Triennial Proceeding 2

(NDCTP) in D.03-10-015, D.07-01-003, and D.10-07-047. The advice letters explicitly reference these 3

approved escalation rates.4

Dr. Paul Hunt’s testimony in support of the application for permanent inclusion of the 5

SGRP costs in rates filed on March 15, 2013 supports the reasonableness of the use of the Handy 6

Whitman Index. The selection of an escalation rate, however, ultimately does not affect customers. The 7

Commission will determine the actual (recorded) removal and disposal costs to be recovered in rates. 8

All amounts SCE has recovered to date will be deducted from the actual (recorded) costs in setting rates. 9

As shown on Line No. 12 of Table II-1, SCE has already recovered $21.62 million (nominal$) for 10

removal and disposal of the original steam generators. The $21.62 million (nominal$) is recorded as 11

accumulated depreciation on SCE’s general ledger and offsets SCE’s rate base. The amount remaining 12

to be recovered through future depreciation is the actual removal and disposal costs in excess of the 13

$21.62 million (nominal$) already recovered from customers. 14

2. Implementation of Provisional SGRP Ratemaking 15

In addition to allowing SCE to recover an estimate of 20% of the removal and disposal 16

costs before the SGRP was completed, D.05-12-040 authorized SCE to implement ratemaking to 17

provisionally recover additional SGRP revenue requirements once certain activities were completed, but 18

before the final review of the costs had been performed. 19

Specifically, D.05-12-040 authorized SCE to: 20

� Establish a balancing account to record steam generator replacement costs 21

revenue requirements commencing on the return-to-service dates of each unit and 22

to include the revenue requirements in rates, subject to refund, commencing on 23

January 1st of the year following the return-to-service dates of each unit. 24

� Establish a balancing account to record removal and disposal costs revenue 25

requirement for the original steam generators, and include the revenue 26

requirements in interim rates (through advice letters) commencing on January 1st27

5

of each year following completion of removal and disposal activities for each 1

unit. 2

In compliance with D.05-12-040, SCE filed Advice Letter 2355-E to establish the 3

SONGS 2&3 Steam Generator Replacement Balancing Account (SGRBA), and the SONGS 2&3 Steam 4

Generator Removal and Disposal Balancing Account (SGRDBA) to record the SGRP revenue 5

requirements, and to modify the existing Base Revenue Requirement Balancing Account (BBRBA). 6

Through the operation of these three balancing accounts, SCE implemented a two-step process to ensure 7

that no more than the revenue requirement based on actual (recorded) costs would be recovered from 8

customers during this interim rate recovery period.9

The first step is to include an estimate of the annual SGRP revenue requirement in rates 10

beginning January 1st following the date when the replacement unit was operational and January 1st of 11

the year following completion of the removal and disposal work. This was accomplished via the three 12

advice letters referenced in the ALJ’s February 13, 2012 ruling (i.e. Advice Letters 2521-E, 2648-E, and 13

2834-E).14

The second step is to true-up the revenue received from customers through rates that were 15

set based on the estimated revenue requirement to a revenue requirement based on actual (recorded) 16

costs as recorded in the SGRBA and SGRDBA. This second step is accomplished through the operation 17

of the BRRBA. Specifically, SCE compares revenue from customer rates (including the estimated 18

SGRP revenue requirement) with authorized revenue requirements (i.e. GRC revenue requirement) and 19

other costs including the SGRP revenue requirements computed based on actual (recorded) costs.3 The 20

year-end balance (over- or under-collection) recorded in the BRRBA is then reviewed for inclusion in 21

rates in the subsequent year as part of SCE’s annual Energy Resource Recovery Account (ERRA) 22

Forecast proceedings. Annual over- and under- collections are either refunded to, or recovered from, 23

customers through rates in the subsequent year. 24

3 The revenue requirements recorded in the SGRP balancing accounts are transferred to the BRRBA each month.

6

Based on these two steps, in the year following the completion of certain SGRP activities 1

(such as the installation of a replacement steam generator),4 SCE included in rates an estimate of the 2

annual revenue requirement for the year, plus a true-up of the previous year’s estimate. 3

B. Recorded SGRP Revenue Requirements 4

Table II-2 below shows the recorded revenue requirement by year through 2012.55

Table II-2 Recorded SGRP Revenue Requirement

2006 through 2012 ($millions, nominal$)

A B C D E F G H I JTotal�Thru Remaining Total

2006 2007 2008 2009 2010 2011 2012 2012 Plant�1/ Plant�2/

1. Recorded�Depreciation2. Estimated�20%�of�Removal�and�Disposal 3.03�� 3.32�� 3.59�� 3.78�� 3.84�� 4.06�� 21.62��3. Recorded�in�SGRBA�and�SGRDBA �� 15.62�� 42.58�� 51.73�� 109.93��4. Subtotal�Depreciation�(Recovery�of�Plant) 3.03�� 3.32�� 3.59�� 3.78�� 19.46�� 46.64�� 51.73�� 131.55�� 567.85�� 699.40��

5. Property�Taxes�(Recorded�in�SGRBA) �� 1.60�� 4.82�� 6.42��

6. Income�Taxes�(Recorded�in�SGRBA�and�SGRDBA) �� 8.06�� 10.48�� 11.27�� 29.80��

7. Return�on�Rate�Base�(Recorded�in�SGRBA�and�SGRDBA) �� 16.72�� 39.99�� 41.14�� 97.85��8. Subtotal�without�FF&U 3.03�� 3.32�� 3.59�� 3.78�� 44.24�� 98.71�� 108.97�� 265.63��

9. Franchise�Fees�and�Uncollectibles 0.03�� 0.04�� 0.05�� 0.04�� 0.51�� 1.14�� 1.22�� 3.04��10. Total�Recorded�Revenue�Requirement 3.06�� 3.36�� 3.64�� 3.82�� 44.75�� 99.85�� 110.19�� 268.67��

��NOTES:��1/��Total�Plant�remaining�to�be�amortized�and�recovered�in�rates�through�the�end�of�the�NRC�license�period�which�is�2022�(i.e.�10�years).��2/��Total�Plant�includes�approximately�$90.3�million�of�accrued�AFUDC�and�$8.0�million�of�capitalized�property�taxes.

As shown on Line No. 10 in Column H, through the end of 2012, SCE recorded a total 6

SGRP revenue requirement of $268.67 million (nominal$). As shown in Column I, there is still $567.85 7

million (nominal$) of SGRP plant remaining to be recovered, plus taxes and return. In the application 8

for permanent inclusion of the SGRP costs in rates filed on March 15, 2013, SCE is requesting that these 9

recorded revenue requirements no longer be subject to refund, and that SCE be able to continue to 10

recover its on-going SGRP revenue requirement necessary to recover the $567.85 million (nominal$) 11

remaining plant in rates through 2022. 12

4 The replacement units were operational and the removal and disposal work was complete. 5 The annual amounts shown in Table II-2 include adjustments recorded in subsequent years.

7

Table II-3 below shows how SCE recovered its SGRP revenue requirement recorded 1

through December 31, 2012 in the amount of $268.67 million (nominal$) in rates using the two-step 2

process discussed above. 3

Table II-3 SGRP Revenue Requirement

Included in Rates 2006 through 2013

($millions, nominal$) 2006 2007 2008 2009 2010 2011 2012 2013�2/ Total

1. 20%�of�the�est.�Removal�and�Displ.�Rev�Rqmt 3.06�� 3.36�� 3.64�� 3.82�� 3.88�� 4.11�� 21.87��

2. Estimated�Annual�Replacement�Rev�Rqmt�Unit�2 56.69�� 57.70�� 114.39��3. Estimated�Annual�Replacement�Rev�Rqmt�Unit�3 �� 57.54�� 57.54��4. Subtotal 56.69�� 115.24�� 171.93��

5. Prior�Year�True�Up�Recorded�In�BRRBA�Included�In�Rates ��6. ��Recorded�2010�Unit�2�Rev�Rqmt 40.87�� 40.87��7. ��Recorded�2011�Unit�3�Rev�Rqmt 45.25�� 45.25��8. ��Prior�Year�Replacement�Rev�Rqmt�True�up�1/ 2.61�� 6.83�� 9.44��9. ��Recorded�2011�and�2012�Unit�2�&�3�R&D�Rev�Rqmt�3/ (8.81)�� (11.88)�� (20.69)��

10. Total�In�Rates�Each�Year 3.06�� 3.36�� 3.64�� 3.82�� 3.88�� 101.67�� 154.29�� (5.05)�� 268.67��

1/��2012��Difference�between�$56.69M�in�rates�and�the�recorded�amount�(including�FF&U)�of�$59.30M��2013��Difference�between�$115.24M�in�rates�and�the�recorded�amount�(including�FF&U)�of�$122.07M

2/��For�purposes�of�showing�how�SCE�has�recovered�its�recorded�SGRP�revenue�requirement��through�2012,�the�2013�SGRP�revenue�requirement��currently�in�2013�rates�is�not�shown�in�this�table.

3/��As�explained�in�more�detail�below,�prior�to�the�completion�of�the�removal�and�disposal�work,�SCE�realized�a�tax�deduction�as�cash�expenditures��for�removal�and�disposal�work�were�spent.��As�such,�SCE�recorded�the�associated�credit�revenue�requirement�in�the�SGRDBA.��In�addition,��SCE�recorded�a�credit�revenue�requirement�associated�with�the�removal�and�disposal�accumulated�depreciation�(i.e.�rate�base�deduction)��that�was�recovered�during��2006�through�2011.

The revenue requirements shown on Line No. 1 of Table II-3 are the amounts included in 4

rates implemented through the advice letters shown in Table II-3 above. The revenue requirements 5

shown on Line No. 4 are the revenue requirements included in Advice Letters 2521-E and 2648-E.66

C. Calculation Of The SGRP Revenue Requirements 7

As supported in SCE’s March 15, 2013 application for permanent inclusion of the SGRP costs in 8

rates, SCE’s share of the SGRP capital expenditures, including corporate overheads, is $601.1 million 9

(nominal$). This amount excludes Allowances for Funds Used During Construction (AFUDC) and 10

capitalized property taxes. As SCE spent the capital expenditures required by the SGRP, overheads 11

6 As indicated in Note No. 2 in Table II-3, the estimated 2013 SGRP revenue requirement is not included here.

8

including AFUDC are added each month. As shown in Column J in Table II-2 above, including 1

AFUDC and capitalized property taxes, the total amount of plant to be recovered is $699.4 million 2

(nominal$). As such, SCE’s SGRP revenue requirements are calculated to recover the $699.4 million 3

(nominal$) over the current license period for SONGS 2&3. 4

Once the replacement steam generators were operational and the removal and disposal work was 5

complete, the total of the expenditures and overheads was added to rate base. At that time, accrual of 6

AFUDC and property taxes ceased and SCE began to depreciate the net plant (i.e. gross plant less 7

accumulated depreciation). It is also at that time, consistent with D.05-12-040, that SCE began to record 8

the revenue requirement (i.e. depreciation, property taxes, income taxes and return on rate base) in the 9

SGRP balancing accounts.10

1. Depreciation Expense 11

Depreciation expense for plant in service is calculated on a straight line basis consistent 12

with CPUC authorized average remaining lives for SONGS FERC plant accounts.7 The average 13

remaining lives are a function of the remaining license life, and adjusted for estimated interim 14

retirements (i.e. asset retirements that will occur prior to the end of the license life). Depreciation 15

expense related to the removal and disposal costs for the SGRP was and will be accrued consistent with 16

D.05-12-040. Twenty percent of the removal and disposal estimate was amortized over the 2006-2011 17

period, and the remaining portion (incurred cost less the amount previously amortized) will be amortized 18

over the remaining life starting from the completion of the project. 19

2. Property Taxes 20

Property taxes are calculated based on the value of plant as of the property tax lien date 21

multiplied by a property tax factor based on the historical relationship of property tax assessments to 22

recorded plant balances. 23

7 Depreciation parameters used for the 2009-2010 period were authorized in D.09-03-025 (2009 GRC) and depreciation parameters for 2012-2014 were authorized in D.12-11-051 (2012 GRC).

9

3. Federal and State Income Taxes 1

For SGRBA related costs, SCE capitalizes the costs of acquiring, transporting and 2

installing the steam generators for tax purposes, and depreciates these capitalized costs pursuant to the 3

applicable Modified Accelerated Cost Recovery System (MACRS) method for Federal tax purposes and 4

Asset Depreciation Range System for state purposes. Because SCE is using MACRS accelerated tax 5

depreciation method for federal tax purposes, SCE must use the normalization method of accounting to 6

compute its income tax expense for ratemaking purposes, which requires SCE to record deferred income 7

taxes to reflect any differences between the federal MACRS tax depreciation and the book depreciation 8

computed on the tax basis of those assets. For SGRDBA related costs, SCE deducts the costs to remove, 9

segment and ship offsite the original steam generators, as well as deducts any remaining net tax basis of 10

the original steam generators when these assets are removed as an abandonment loss for tax purposes. 11

4. Return on Rate Base 12

Return on rate base is calculated by multiplying the average recorded rate base by the 13

currently authorized rate of return authorized by the Commission. 14

The ALJ’s February 21, 2013 ruling directed SCE to explain how the SGRP revenue 15

requirements were calculated. The above methodology for calculating the SGRP revenue requirement 16

was used to calculate both the estimated annual revenue requirements included in Advice Letters 2521-17

E, 2648-E, and 2834-E and the revenue requirement recorded in the SGRBA and SGRDBA.18

Differences between those estimated annual revenue requirements and the actual revenue requirements 19

will result due to things such as, estimated plant being different than the recorded plant, tax rates 20

changes (if any), and changes in authorized rates of return. 21

10

III. 1

SGRP EXPENSES 2

In response to Question No. 3 posed in the February 21, 2013 ALJ Ruling, Table III-4 below 3

provides a summary of the steam generator inspection and repair activities in excess of $1M that are 4

included in the "Monthly Report in Compliance with I.12-10-013" dated February 1, 2013, and 5

categorized as "Investigation" and "Repairs - After Outage."86

Table III-4 2012 O&M Steam Generator Inspection and Repair Costs

Orders in Excess of $1 Million ($ in Thousands)

Description Order 100% SCE Share

Investigation:Unit 2:Eddy Current Testing and Tube Plugging 800589922 27,606.5 21,591.0Steam Generator Repair Work -- Design Engineering Org 800843405 5,435.5 4,251.1Tube Stabilizer 800933319 1,107.9 866.5Unit 3:Steam Generator Forced Outage -- Vendor Support 800840831 29,914.5 23,396.1Steam Generator Repair Work -- Design Engineering Org 800843403 2,921.0 2,284.5Forced Outage Support -- Health Physics 800840809 2,011.4 1,573.1Forced Outage Support -- Project Management Org 800840786 1,823.6 1,426.2Forced Outage Support -- Plant Engrg & Engrg Programs 800842686 1,308.1 1,023.0

Repairs - After Outage:Unit 2:Tube Stabilizer 800933319 17,731.8 13,868.0Eddy Current Testing and Tube Plugging (E088) 800589922 3,386.8 2,648.8Steam Generator Repair Work -- Design Engineering Org 800843405 1,848.4 1,445.6Eddy Current Testing and Tube Plugging (E089) 800589928 1,641.0 1,283.4Unit 3:Eddy Current Testing and Tube Plugging (E088) 800842826 3,801.1 2,972.8Eddy Current Testing and Tube Plugging (E089) 800842830 2,893.6 2,263.1

SONGS recorded costs are captured in SCE's financial reporting program (SAP) by Order; 7

therefore, these reports identify work activities by Order. Appendix B provides a detailed list of all 8

2012 costs comprising the Investigation and Repairs - After Outage, sorted by category, for Units 2 & 3 9

8 In SCE-4 Appendix 4, SCE provided the 2012 Recorded Costs for the Steam Generator Inspection and Repair Activities (100% level).

11

combined. The activities are sorted by dollar amount and costs are provided in both 100% level and 1

SCE Share. 2

To provide further detail, Appendix C includes the costs for all Steam Generator Inspection and 3

Repair activities (including Regulatory - After Outage, and Defueling), showing Unit 2 and Unit 3 costs 4

separately. This report is also broken down by Functional Group to allow for correlation with work 5

descriptions provided in the General Rate Case. These costs are provided in both 100% level and SCE 6

Share. 7

As a significant portion of the steam generator costs are contractor- and consultant-related, 8

Appendix D provides a report that identifies all vendor costs, by Functional Group, and by activity 9

(order), at 100% level. 10

For reference purposes, Appendix E includes the generic SONGS Acronym List. 11

12

IV.1

CONCLUSION 2

This concludes SCE’s testimony in response to the February 21, 2013 ALJ Ruling. 3

Appendix A

Witness Qualifications

A-1

SOUTHERN CALIFORNIA EDISON COMPANY 1

QUALIFICATIONS AND PREPARED TESTIMONY 2

OF JOSE LUIS PEREZ 3

Q. Please state your name and business address for the record. 4

A. My name is Jose Luis Perez, and my business address is 8631 Rush Street, Rosemead, CA 91770. 5

Q. Briefly describe your present responsibilities at the Southern California Edison Company. 6

A. I manage the Generation Planning and Strategy organization. 7

Q. Briefly describe your educational and professional background. 8

A. I earned an MBA from the University of California, Irvine in 1997. I earned a Bachelor of Science 9

Degree in Civil Engineering from California State University, Long Beach in 1977. I am a 10

Registered Professional Engineer and a Licensed General Contractor in the State of California. Prior 11

to joining Edison, my professional background included various home office and jobsite positions in 12

the civil engineering and scheduling organizations of Bechtel Power Corporation and the collection 13

and analysis of construction cost data for publication in cost estimating manuals for Marshall and 14

Swift Publications. Since joining Edison in 1982, I have held various management positions in the 15

business planning groups of the Generation Business Unit. In addition, I managed various projects, 16

including SONGS Unit 1 decommissioning shortly after permanent shutdown, and various activities 17

in support of the industry restructuring efforts. 18

Q. What is the purpose of your testimony in this proceeding? 19

A. The purpose of my testimony in this proceeding is to sponsor the portions of Exhibit SCE-5, entitled 20

SCE’s Testimony In Response to February 21, 2013 Ruling as identified in the Tables of Contents 21

thereto.22

Q. Was this material prepared by you or under your supervision? 23

A. Yes, it was. 24

Q. Insofar as this material is factual in nature, do you believe it to be correct? 25

A. Yes, I do. 26

Q. Insofar as this material is in the nature of opinion or judgment, does it represent your best judgment? 27

A-2

A. Yes, it does. 1

Q. Does this conclude your qualifications and prepared testimony? 2

A. Yes, it does. 3

A-3

SOUTHERN CALIFORNIA EDISON COMPANY 1

QUALIFICATIONS AND PREPARED TESTIMONY 2

OF DOUGLAS A. SNOW 3

Q. Please state your name and business address for the record. 4

A. My name is Douglas A. Snow, and my business address is 8631 Rush Street, Rosemead, California 5

91770.6

Q. Briefly describe your present responsibilities at the Southern California Edison Company (SCE). 7

A. I am the Director of CPUC Revenue Requirements and Tariffs in SCE’s Regulatory Operations 8

Department. As such, I am responsible for the recovery of SCE’s authorized revenue requirements 9

and oversee the operation of various balancing and memorandum accounts, including the recovery of 10

the balances in those accounts, and I am responsible for managing the implementation of SCE’s 11

tariffs and advice letters. 12

Q. Briefly describe your educational and professional background. 13

A. I graduated from Texas A&M University in May of 1982 with a Bachelor of Science Degree in 14

Industrial Engineering. In June of 1982, I went to work for Southwestern Public Service Company 15

(SPS) in west Texas. While there, I was a supervisory engineer, responsible for revenue requirement 16

calculations and rate design for both retail and resale customers. I filed testimony on behalf of SPS 17

before the Texas Public Utility Commission and the Federal Energy Regulatory Commission. In 18

November of 1993, I began to work for the Southern California Edison Company as a financial 19

analyst in the FERC Pricing section in the RP&A Department. While working in the FERC section, 20

I was responsible for the rate design for SCE’s requirements sales for resale, Wheeling Access 21

Charges, and wholesale Distribution Access Charges. In March 1998, I became a supervisor in the 22

Revenue Requirements division of RP&A, responsible for supervising a group of analysts that 23

oversee the forecasting and recording entries associated with all CPUC regulatory mechanisms. In 24

December 2001, I was promoted to the position of manager in the Revenue Requirements division of 25

RP&A. In August 2006, I was promoted to Manager of CPUC Revenue Requirements, and in 26

March 2013, I became the Director of CPUC Revenue Requirements and Tariffs taking on the 27

A-4

additional responsibilities for managing SCE’s tariffs. I have previously testified before the 1

California Public Utilities Commission. 2

Q. What is the purpose of your testimony in this proceeding? 3

A. The purpose of my testimony in this proceeding is to sponsor portions of Exhibit SCE-5, entitled 4

SCE’s Testimony In Response to February 21, 2013 Ruling, as identified in the Table of Contents 5

thereto.6

Q. Was this material prepared by you or under your supervision? 7

A. Yes, it was. 8

Q. Insofar as this material is factual in nature, do you believe it to be correct? 9

A. Yes, I do. 10

Q. Insofar as this material is in the nature of opinion or judgment, does it represent your best judgment? 11

A. Yes, it does. 12

Q. Does this conclude your qualifications and prepared testimony? 13

A. Yes, it does.14

Appendix B

(2012�Recorded�Costs)

Order Order�Description 100%�Level SCE�Share800840831 Vendor�cost�collector�U3�SG�Forced�Otg�2 29,914,508.42 23,396,137.04800589922 2E088�Eddy�Current�Testing�and�Tube�Plug 27,606,503.13 21,591,046.10800843405 U2�Direct�SGR�Work�DEO 5,435,453.02 4,251,067.81800843403 U3�Forced�Direct�SGR�Work�DEO 2,920,975.43 2,284,494.88800840809 U3�Forced�Outage�U3SG088��Health�Physics 2,011,407.27 1,573,121.63800840786 U3�Forced�Outage�Support��PMO�Division 1,823,596.90 1,426,235.14800842686 U3�Forced�Direct�SGR�Work�PEEP 1,308,051.61 1,023,027.16800933319 2E089�Split�Stabilizer:�ASC�D0064420�and 1,107,903.78 866,491.55800840807 PEEP�Support�for�U3�unscheduled�outage 891,546.44 697,278.47800884356 Sup�Order�Tracking�costs�for�Aux�Blr 846,190.47 661,805.57800847272 U2�Emergent�Work�U2SG088��Health�Physics 833,360.34 651,771.12800847273 U2�Emergent�Work�U2SG089��Health�Physics 766,397.75 599,399.68800911510 2E089�ECT�and�plugs/stabilizers 761,420.42 595,506.91800847266 U3�Forced�Outage�U3SG089��Health�Physics 732,541.22 572,920.49800911398 U2�Return�to�Service�Steam�Generator�PMO 590,974.56 462,201.20800842554 $$�U3�Forced�Outage�2012��NFM 454,691.85 355,614.50800840690 U3�Forced�Outage�Support��Work�Control 447,498.74 349,988.76800921685 Phase�I�U2�Steam�Generator�Repair 397,235.58 310,677.95800930592 Sensor�installation�U2�Containment��VLPM 340,109.73 265,999.82800847482 OPS�Emergent�U2E088�S/G�work 318,847.31 249,370.48800923870 SGR�PH1��Relocate�SGR�Personnel 310,138.23 242,559.11800589928 2E089�Eddy�Current�Testing�and�Tube�Plug 300,945.51 235,369.48800840785 U3�Forced�Outage�Support��Operations�Di 294,555.18 230,371.61800873488 Unit�2�SG�Return�to�Service 268,987.86 210,375.41800861087 Remove/Reinstall�90�deg.�handhole�cover 255,903.31 200,141.98800847487 OPS�Emergent�U2E089�S/G�work 238,998.19 186,920.48800840767 U3�Forced�Outage�Support��Maintenance�D 220,961.53 172,814.01800889200 MATERIAL�ONLY�for�AUX�Boiler 215,449.88 168,503.35800869587 SET�UP�TO�"RECIRC"�THE�SECONDAY�COND.�SY 212,210.83 165,970.09800911440 U3�Return�to�Service�Steam�Generator�PMO 187,291.64 146,480.79800847485 OPS�Emergent�U3E088�S/G�work 175,714.15 137,426.04800847486 OPS�Emergent�U3E089�S/G�work 148,107.58 115,834.94800842079 SSS�U3�Forced�Outage�Common�Costs�split 110,694.29 86,574.00800843944 U2�:�2E089�IN�SITU�Testing�U2C17�Refuel 103,750.00 81,142.88800845381 U3�Forced�Outage��PI�Support 100,421.09 78,539.33

Investigation

Prepared:�EW,�B&FSB-1


Order Order�Description 100%�Level SCE�Share

Investigation

800942977 U2&3�Return�To�Service��Division�Support 94,899.24 74,220.70800840810 U3�Forced�Outage�U3SG088��Chemistry�Supp 90,186.31 70,534.71800882289 U2�Emergent�Work�U2SG��PI�Support 88,229.99 69,004.68800842674 U3�temporary�power�forced�outage 86,814.80 67,897.86800888101 Scaffold�support�for�the�installation�of 81,188.09 63,497.21800930593 U2�Containment��VLPMS�Upgrade�ASC�2 80,057.51 62,612.98800859421 $$�U3�Direct�SGR�Work�NFM 77,808.41 60,853.96800840830 U3�E088�direct�work�cost�collector�Force 72,131.56 56,414.09800928623 SGR_Team�Eng�Initiation 70,246.76 54,939.99800841295 Security�U3�Forced�Outage�2012 70,011.27 54,755.81800842575 SUPPORT�ORDER�TO�OPEN/CLOSE�UNIT�3�EQUIP 66,920.67 52,338.66800692198 Remove�S31301ME088�HOT�and�COLD�Leg�Manw 65,444.62 51,184.24800843418 Scaffold�S31301ME089�Handholes 61,289.42 47,934.46800928803 SGR_Team�Construction�Planning�&�Prep 59,115.30 46,234.08800847562 SSS�U2�SG�Emergent�Inspections�&�Repairs 57,098.27 44,656.56800841185 Scaffold�S31301ME088�Handholes 56,860.62 44,470.69800857983 Install�Alternate�DLMS�Transducer 50,811.56 39,739.72800897108 Aux�Boiler/Pre�fab�&�Stage�Cables�in�PA 48,661.74 38,058.35800888564 AuxBoiler�InsIall�road�plates/park�trail 46,862.40 36,651.08800846553 Remove/reinstall�secondary�manways�3ME08 39,825.64 31,147.63800928624 SGR_Team�Eng�Planning�&�Prep 38,017.00 29,733.10800893229 Install;�piping�manifolds,�hoses,�and�co 37,913.33 29,652.02800846230 2E089�secondary�side�fill�from�hose 36,781.03 28,766.44800850895 2E089�2nd�Camera�inspection�of�secondary 34,858.45 27,262.79800867216 Support�order�to�OPEN/CLOSE�Unit�2�Equip 34,183.71 26,735.08800693574 Install�E089�Hot�and�Cold�Leg�Manways 31,745.08 24,827.83800888820 Fabricate�and�install�the�required�Secur 31,646.98 24,751.10800907137 Temp�Power�U2�Steam�Generator�Tube�Expan 27,750.89 21,703.97800844047 Open�2ME089�secondary�manway(s)/Upper�bu 26,695.02 20,878.18800901903 Pre�Fab�Boiler�Drain�Headers 25,571.36 19,999.36800928628 SGR_Team�Eng�Services 25,169.35 19,684.95800870905 OP's�Scaffold�Dismantle.�Valves�(10L) 25,073.75 19,610.18800692652 Contingency�Install�3E088�Primary�Manway 24,153.72 18,890.62800928634 SGR_Team�Procurement�Training�&�Organiza 24,038.12 18,800.21800911646 U2�SG�Phase�2�Eddy�current�scaffolds 23,750.87 18,575.56




Investigation

800895164 Aux�Boiler�Tempwr�Support.�SWAP�3BI27�28 22,961.42 17,958.13800846427 Perform�3E088�upper�tube�camera�inspecti 21,863.60 17,099.52800928633 SGR_Team�Procurement�Planning�&�Prep 21,835.43 17,077.49800907819 U2�Open/Close�Equip�Hatch 20,896.60 16,343.23800844771 U3�Forced�Outage��NBA�support�to�SG�lea 20,652.24 16,152.12800847685 R/R�2ME088�secondary�manway(s) 19,583.44 15,316.21800842846 U3�:�3E088�N2�Pressure�Test�support�(Feb 19,492.16 15,244.82800914347 Temp�Power�U3�Steam�Generator�Inspection 19,448.00 15,210.28800850553 3E089�and�3E088�Drain�down�Pump��Stage 19,137.14 14,967.16800874281 Replace�thrust�bearing�on�2MP025. 18,568.67 14,522.56800854459 Drain�U3�Steam�Generators�to�FFCPD 17,961.38 14,047.60800850010 2E088�Camera�inspect�upper�tube�bundle 17,679.27 13,826.96800847277 Emergent�Work�for�Maintenance�Division�a 17,098.33 13,372.60800842352 NTD�U3�Forced�Outage�Common�In�process�& 16,441.61 12,858.98800841694 U3�Remove�insulation�verify�mineral�woo 16,106.32 12,596.75800937301 U2�Carp/Insulator�VLPMS�Upgrade�ASC2. 15,841.10 12,389.32800082747 Replace�Flooding�Sensor�3LSH9467�2�(EQ) 15,746.96 12,315.70800850012 U3�E089�camera�inspect�upper�tube�bundle 15,247.18 11,924.82800868171 Security�U2�SGR�Emergent�Work 14,670.08 11,473.47800928635 SGR_Team�Procurement�Materials 13,836.00 10,821.14800911504 U2�Non�tie�in�Install/Remove�SG�Drain�Do 13,776.93 10,774.94800851644 Scaffold.�U�2�ME089�support�upper�hand�h 13,466.13 10,531.86800279112 REMOVE�AND�REINSTALL�PRESSURIZER�MANWAY 13,398.49 10,478.96800891674 REM/INST�RX�HEAD�CEDM�RSPT�VLPM�CABLES 13,163.83 10,295.43800931933 U3�Layup�Team�Support 13,125.00 10,265.06800891675 VENT�THE�CEDMs 12,981.02 10,152.46800850773 U3�:�3E088�"Upper�East"�Handhole�camera 12,974.14 10,147.07800841296 Access�Authorization�U3�Forced�Outage 12,960.57 10,136.46800862698 Vendor�cost�collector�U2�SG�Forced�Outag 12,819.00 10,025.74800845391 U3�Forced�Outage�IT�Comp�&�Telecom�Commo 12,816.14 10,023.50800856386 Scaffold�Support�for�3XM�Work(L3) 11,896.65 9,304.37800841344 Inspect�and�Replace�Filters. 11,795.51 9,225.27800842611 Unit�3�scaffold�ramps�personnel�hatch 11,746.43 9,186.88800840918 Contingent�WO.�U3:�3E088�Remove/Reinstal 11,618.83 9,087.09800865259 Scaffold�S21301ME089�primary�manways 11,151.28 8,721.42




Investigation

800842578 U3�Pen34�for�S/G�Work.�Remove�&�Replace 11,148.79 8,719.47800861089 ��Scaffold.�U�3�ME088�90�Degree�H/H 11,076.72 8,663.10800842721 U3�Scaffold�Pen.�34�Inside�Containment 10,957.25 8,569.67800750973 Remove�/�Replace�Root�Valve 10,385.72 8,122.67800895258 Aux�Boiler�Test�Tempwr�Support 9,975.74 7,802.03800835434 Scaffold�3HV9302�MOVATS�Testing 9,205.97 7,199.99800857416 U2�NFM�T�Cold�Reduction�Restoration 9,200.03 7,195.34800694880 Eddy�Current�Testing�Fiber�Optic�Cable�I 9,056.73 7,083.27800887921 Temporary�Auxiliary�Boiler�installation 9,054.27 7,081.34800850880 Scaffold�E088�U�3�upper�handhole 8,898.21 6,959.29800841957 Unit�3�Fiber�Optic�cable�installation 8,769.41 6,858.56800841992 U3:�3E088�N2�Test�manifold(Feb�2012�Forc 8,766.06 6,855.94800882112 Handrail.�S32126CR014�Machinists�Suppt. 8,145.18 6,370.35800864911 Primary�scaffold�S21301ME088�manways 8,142.41 6,368.18800857062 $$�U2�Direct�SGR�Work�NFM 7,686.62 6,011.71800869589 Perform�dry�layup�for�point�heaters�and 7,619.17 5,958.95800874493 Provide�Temp�C�Panel 7,545.33 5,901.20800847541 Emergent�Work�for�Maintenance�Division�a 7,413.76 5,798.30800850882 Support�order�to�remove�and�reinstall�3M 7,192.87 5,625.54800648227 Perform�an�inspection�of�impacting�"hamm 7,182.24 5,617.23800847314 Scaffold.�3HV4011�MOVAT�&�Mechanical 7,078.33 5,535.96800847542 Emergent�Work�for�Maintenance�Division�a 7,043.22 5,508.50800847278 Emergent�Work�for�Maintenance�Division�a 6,934.79 5,423.70800882500 remove/replace�turning�vane(s) 6,902.21 5,398.22800846550 REMOVE�/�REINSTALL�SECONDARY�MANWAYS 6,771.66 5,296.12800901943 U2�SGR��BUSINESS�SUPPORT.��Charge�this 6,758.00 5,285.43800854485 U2:�Install�flange/cable�fixture�at�pen 6,495.12 5,079.83800842779 Scaffold�3HV2704��Valve��Overhaul 6,491.89 5,077.31800850772 U3�:�3E089,�"Upper�West"�Handhole�camera 6,472.12 5,061.85800309442 MDR�PERIODIC�REPLACEMENT�AND�RESPONSE 6,451.58 5,045.78800890606 2E088�Camera�inspect�upper�tube�bundle 6,310.30 4,935.29800843648 Scaffold.�Shield�Wall�Cavity�Drain�Line 6,241.35 4,881.36800843427 scaffold�at�U3�Ctmt�Control�Point 6,198.58 4,847.91800842328 3HV9202,�Loop�2A�charging�fail�to�close 6,078.65 4,754.11800625228 (LOOP)�PRESSURIZER�PRESS�(SMM�INPUT) 6,078.18 4,753.74




Investigation

800909676 Modify�Security�Concealment�Plates�at�85 5,997.61 4,690.73800841250 FW�Bypass�3HV1106�failed�open�on�RTO 5,993.18 4,687.27800849870 "U3�FORCED�OUTAGE"�Provide�support�to�Op 5,903.63 4,617.23800870566 Scaffold.�S31305MU568�BLANK�flange. 5,898.78 4,613.44800851642 Scaffold�E088�U�2�upper�handhole 5,863.27 4,585.66800922891 3XEF2�:�3E088�Tubesheet�straightness 5,746.90 4,494.65800842577 Scaffold�U3�Pen.�34�Outside�Containment 5,646.64 4,416.24800672512 Support��Carpenters�to�build�Scaffold. 5,588.42 4,370.70800279063 Defeat�Personnel�Hatch�interlocks(forced 5,553.17 4,343.13800850883 Scaffold.�S31301ME089�support 5,400.36 4,223.62800911786 Scaffold�E089�Eddy�Current�U3�SG�Phase�2 5,379.09 4,206.99800665464 FINAL�REPAIR��Replace�1"�gate�valve. 5,315.91 4,157.57800672510 S31201ME087�Scaffold�Support 5,309.83 4,152.82800280858 INSTALL�RCS/REFUEL�CAVITY�WATER�LEVEL 5,226.16 4,087.38800888162 Scaffold.�3RN7871�1�I&C�Inspect�Nozzles 4,935.69 3,860.20800927138 Reference�NN�202077510�3:�Remove�Ladder 4,810.41 3,762.22800621579 (LOOP)�PZR�PRESS�TO�PPS�CALIB 4,795.28 3,750.39800527469 3HV9302�MOVATS�Testing�&�PM 4,786.45 3,743.48800840875 Prepare�Nozzle�Dams�for�U3�Forced�Outage 4,744.16 3,710.41800812619 3P�141�pump�packing�replacement�and�pump 4,687.84 3,666.36800860515 U3�:�3E088�"Upper�West"�Handhole�camera 4,551.17 3,559.47800843283 MEDICAL�U3�Forced�Outage�Common�costs�sp 4,409.79 3,448.90800901688 U3�Forced�Outage��Business�support.��Ch 4,400.00 3,441.24800611033 (LOOP)�PZR�PRESS�TO�PPS�CALIB 4,388.58 3,432.31800700088 Install�NOZZLE�DAMS�in�Steam�Generator 4,336.50 3,391.58800850750 F3C16B�Ops�Hydro�Tempwr�Spt 4,333.53 3,389.25800928631 SGR_Team�Procurement�Initiation 4,320.58 3,379.13800880162 Scaffold.�2HV5102�B&C�Valve�Testing 4,217.40 3,298.43800866752 CLEAN,�INSPECT,�and�REPAIR�TUBE�LEAKS 4,120.40 3,222.56800821035 Open�and�clean�Heat�Exchanger.�Inspect/r 4,047.64 3,165.66800784239 Replace�Electro�Hydraulic�Controller 3,871.16 3,027.63800854484 U2�Pen�34�support��shop�prefab 3,858.18 3,017.48800853211 Perform�Visual�Inspection�on�S/G�Snubber 3,772.08 2,950.14800907136 Pen�34�flange/cable�temp�fixture 3,603.06 2,817.95800875237 Scaffold�S31415ML368A�Welders�Shim�Inst. 3,578.75 2,798.94




Investigation

800850727 Remove/Install�Upper�hand�hole�cover.�27 3,558.96 2,783.46800851640 Remove/Reinstall�handhole�covers�for�ins 3,544.19 2,771.91800700090 Install�NOZZLE�DAMS�in�Steam�Generator 3,543.18 2,771.12800751304 Remove�and�Replace�socket�weld�union. 3,529.76 2,760.63800863332 3A0403�162�Timer�Failed�SV�on�As�Lefts 3,481.09 2,722.56800468031 COLD�CALIBRATE�TO�SUPPORT�OPS 3,440.86 2,691.10800511708 MDR�PERIODIC�REPLACEMENT�AND�RESPONSE�T 3,426.25 2,679.67800888163 Scaffold.�2RN7871�1�I&C�Inspect�Nozzles 3,424.22 2,678.08800205998 LEAD�Align�Motor�Spool,�Bag�Seal,�Pump�s 3,364.64 2,631.48800859777 Insulator�Support:�Remove�Insulation�on 3,310.72 2,589.31800864440 Security�Support�for�U2�S/G�Insp. 3,249.38 2,541.34800859879 Support,�remove�/�install�insulation 3,229.28 2,525.62800606392 LINESTARTER�CLEAN,�INSPECT�AND�ADJUST 3,217.96 2,516.77800928636 SGR_Team�Procurement�Services 3,211.04 2,511.35800682176 Weld��Final�repairs�on�flange 3,185.53 2,491.40800850884 Need�insulation�removal/installation�to 3,160.74 2,472.01800758720 Weld_�Final�repairs.�Two�valves 3,128.55 2,446.84800267306 FILL�AND�VENT�CTMT�XMTRS�/�SENS�LINES 3,111.91 2,433.82800860708 Remove/Reinstall�3E088�90�deg.�handhole 3,089.74 2,416.49800334085 UNIT�3�CNTMT�EARLY�WARNING�FIRE�DETECTI 3,056.96 2,390.85800846557 Scaffold�S31301ME088�Gin�Wheels 3,043.77 2,380.53800928629 SGR_Team�Eng�Travel 3,000.00 2,346.30800847308 Heat�up�valve�body. 2,914.74 2,279.62800854526 U3�Non�WAR�S/G�drain�activities 2,914.34 2,279.31800841181 Insulation�Handhold�Unit�3�Forced�Outage 2,886.58 2,257.59800828080 Inspect/Repair�Interior�S31203ME001 2,822.68 2,207.62800853623 3D105��MCCB�Replacement�/�Testing 2,798.23 2,188.50800625229 (LOOP)�PRESSURIZER�PRESS�(SMM�INPUT) 2,794.40 2,185.50800861088 Installation�of�U2�nozzle�dam�ME089P 2,775.98 2,171.09800872396 Repair�U2�Pen�34�temp�flange/cable�seal 2,768.13 2,164.95800861518 Installation�of�U2�nozzle�dam�ME088P 2,754.30 2,154.14800864850 Replace�3PT0102�1�(10CFR21�Issue) 2,705.57 2,116.03800776783 3BM39��Replace�Open/Close�Contactor��S 2,682.79 2,098.21800883301 Scaffold.�3PCV2883�Valve�Testing 2,664.59 2,083.98800844479 Scaffold:�Working�platform 2,506.93 1,960.67




Investigation

800928801 SGR_Team�Construction�Initiation 2,497.68 1,953.44800860738 Remove�/�Replace�Insulation 2,451.91 1,917.64800867320 Turbine�vib�high�ann.�for�unknown�reason 2,414.31 1,888.23800855479 Determine�Status�of�Conservator�Bladders 2,336.78 1,827.60800843301 R3C16�forced�Remove/Reinstall�3HV274�Ins 2,327.15 1,820.06800916232 Sheet�Metal�Support�Per�NECP 2,244.00 1,755.03800868014 Scaffold��shielding�U�2�Containment 2,216.68 1,733.67800855793 Provide�Temp�C�Panel 2,201.33 1,721.66800916230 Fabricate�(2)�Stands�per�NECP 2,186.79 1,710.29800851614 U2�E089�"Upper�East"�(270�degree)�Hand�h 2,156.77 1,686.81800877994 Insulation�S21301ME088�Secondary�Man�Way 2,104.00 1,645.54800877417 Scaffold.�S31305MR302�Mach.�Vavle�Repl. 2,078.08 1,625.27800283944 Install�DLMS�during�OUTAGES 2,035.65 1,592.08800837151 Perform�AOV�diagnostic�testing 2,011.50 1,573.19800928625 SGR_Team�Eng�Training�&�Organizational�D 1,992.83 1,558.59800283946 REMOVE�AND�REINSTALL�PRES.�manway�Ins. 1,974.34 1,544.13800905313 Install�U2�N16�Gamma�Detect�Sys�(TECP) 1,944.89 1,521.10800279103 INSTALL/REMOVE�PZR�VENT�RIGS�AS�DIRECTE 1,927.73 1,507.68800692190 Remove�E089�Hot�and�Cold�Leg�Manways. 1,827.99 1,429.67800511874 3L035�K624�MDR�Replacement 1,816.01 1,420.30800892096 R/R�Insulation.�SA1312MR171�Replacement. 1,796.45 1,405.00800281544 GENERAL�PANEL�INSPECTION 1,782.74 1,394.28800852141 Need�to�re�open�2E089�secondary�manways 1,779.68 1,391.89800855604 Broken�Concrete�on�U3�MFW�P�062�Support 1,741.21 1,361.80800828081 Install/Remove�drain�down�hoses. 1,722.72 1,347.34800866753 Paint.�S31203ME001�Inspection. 1,575.15 1,231.92800848125 Scaffold:�Working�platform�E088 1,544.88 1,208.25800841180 Insulation.�Manway�Unit�3�Forced�Outage 1,446.86 1,131.59800279756 JUMPER�ALM�CONTACTS�FOR�DRAIN�DOWN 1,446.52 1,131.32800851643 Remove/Reinstall�insulation 1,434.92 1,122.25800283945 Perform�DLMS�level�correlations�after�t 1,423.02 1,112.94800843419 Insulation�S31301ME089�Man�way�Removal 1,418.94 1,109.75800881842 Install�/�Remove�Stop�Log 1,395.00 1,091.03800853624 3D304��MCCB�Replacement�/�Testing 1,342.37 1,049.87800849874 "U3�FORCED�OUTAGE"�Provide�support�to�OT 1,335.60 1,044.57




Investigation

800281519 GENERAL�PANEL�INSPECTION 1,298.97 1,015.92800846556 Insulation�S31301ME088�Secondary�m/w�rem 1,294.00 1,012.04800843300 REJECT 1,287.50 1,006.95800840808 DEO�Support�for�U3�unscheduled�outage 1,194.78 934.44800842291 3HV4011�Reset�Limit�Switch 1,143.25 894.14800283948 INSTALL/REMOVE�INSPECTION�PLATFORM(Sky 1,057.57 827.13800861090 Insulation�U�3�ME088�Hand�hole�90�Deg. 1,052.00 822.77800872043 Remove/Reinstall,�and/or�Fabricate�insul 1,049.28 820.64800468034 COLD�CALIBRATE�TO�SUPPORT�OPS 1,048.74 820.22800249839 RESPONSE�TIME�TEST�3L035K724 1,041.89 814.86800842930 Troubleshoot�heater�control�problem 1,037.35 811.31800781948 Gen�Brush�Gear�Retrieve�Loose�Bolts�&�fo 1,026.70 802.98800282118 COLD�CALIBRATE�TO�SUPPORT�OPS 1,009.01 789.15800882298 Unit�2�Emergent�Work�U2SG��CNO�Support 1,000.00 782.10800898942 AREVA�Engineering�support�activities 991.00 775.06800882621 3WB116�Water�Box�cleaning 970.90 759.34800841254 U3�Forced�Otg��B&FS�support��Charge 967.87 756.97800841839 U3�Forced�Outage�Regulatory�Projects�sup 953.42 745.67800700091 Remove�NOZZLE�DAMS�from�Steam�Generator. 950.39 743.30800879599 Unit�2�CEAC�2�failure 929.01 726.58800823358 Remove�and�Replace�S31301MU880 860.39 672.91800844477 Insulation�S21301ME089�Secondary�m/w�rem 856.99 670.25800947094 U2�RTS�Misc�Expenses�FERC�524,�SG�Return 811.52 634.69800882299 U3�SG�Emergent�Work��CNO�Support 800.00 625.68800840811 U3�Force�Outage��HU�and�Industrial�Safe 799.09 624.97800928804 SGR_Team�Construction�Training�&�Organiz 757.69 592.59800769784 Build�Scaffolding�to�access�PIPING. 755.40 590.80800851645 Remove/Reinstall�insulation�U�2 713.04 557.67800873108 �Divers��Support�to�investigate/repair 697.47 545.49800847311 R/R�Insulation.�3HV4011�heat�blanket�ins 661.22 517.14800912755 Modify�existing�Security�Concealment�Bar 642.24 502.30800282100 COLD�CALIBRATE�TO�SUPPORT�OPS 628.05 491.20800776093 DISABLE�DCS�ALARMS�FOR�OUTAGE 628.05 491.20800912703 Insulation�R/R.�3RN7871�1�Nozzle�inspect 627.03 490.40800826320 Replace�Union 576.51 450.89




Investigation

800843266 3CEA78�1�Intermittent�Failure�Support 569.01 445.02800850739 Remove/Reinstall�handhole�covers�for�ins 533.22 417.03800846563 S31301ME089.�Insulation�Secondary�Manway 524.64 410.32800334142 FO3�UNIT�3�CNTMT�ACTUATION�DETECTORS�SUR 502.35 392.89800845641 E&TS�Support�work�for�U3�Forced�Outage 448.96 351.13800859132 U2�DEO�T�Cold�Reduction�Restoration 431.12 337.18800854026 3HV0299��Determ/Reterm�Target�Rock 415.95 325.31800847483 WC�Emergent�U3088�S/G�work 360.35 281.83800885501 Exercise�LP�Turbine�Valves 305.40 238.85800891098 Remove�/�Replace�SA1312MR171 297.69 232.82800877567 Correct�Leaking�Booster�Relay 280.98 219.75800890532 HJTC�Heater�Fuse�Removal�&�Replacement 271.64 212.45800283947 ANNUAL�CERTIFICATION�INSPECTION�AND�NDE 235.96 184.54800694881 Pen34�for�S/G�Work.�Remove�&�Replace�Pen 232.95 182.19800921093 2XEF2�:�2E088�Remove�plugs�and�stabilize 221.97 173.60800869215 Preventively�Cycle�Main�Turbine�LP�Vv's 218.60 170.97800885508 Exercise�LP�Turbine�Valves 203.13 158.87800918219 U2�SG�Emergent�Work��NBA�support�to�SG 199.25 155.83800683887 Correct�TCBO�Reading�on�Recorder 186.58 145.92800842590 Correct�Sticking�Letdown�Valve�Control 186.58 145.92800862597 Install�new�RDBs�in�CPCs�A,B,C,D 178.92 139.93800784453 Verify�UA�Diff�Press�Button�in�SHOP 174.01 136.09800734613 Steam�Trap�Valve�Leakby 169.09 132.25800253623 Paint�S31305MR123�and�supports 157.74 123.37800853487 Clean�the�motor�housing�breathers. 150.31 117.56800607135 LINESTARTER�CLEAN,�INSPECT�AND�ADJUST 150.00 117.32800885393 Power�flush�pump�inboard�/�outboard�bear 147.80 115.59800700089 Remove�NOZZLE�DAMS�from�Steam�Generator. 145.05 113.44800876254 Remove�/�Replace�Valve�S31305MR302 144.77 113.22800878113 R/R�2ME088�secondary�manway(s) 143.55 112.27800890531 HJTC�Heater�Fuse�Removal�&�Replacement 135.82 106.22800845380 U3�Forced�Outage��NOD�Support 83.33 65.17800914999 Remove/Reinstall�handhole�covers�for�ins 78.17 61.14800915050 U3�Pen�34�temp�service�head 35.67 27.90800249836 RESPONSE�TIME�TEST�3L035K624 33.96 26.56




Investigation

800914400 Scaffold�E088�Eddy�Current�U3�SG�Phase�2 30.97 24.22800932343 U3LU�Transfer�dry�lay�up�supply�air�to�R 15.63 12.22800927426 Install�covers�on�U3�Rx�Cavity�Clg�Fans. 8.12 6.35800842827 U3�:�3E088�Sec.�Side�FOSAR�(Feb�2012�For (25.39) (19.86)800589931 E089�Divider�Plate�Ultrasonic�Testing (585.33) (457.79)800845843 2E089�upper�tube�bundle�camera�inspectio (840.69) (657.50)800910082 Replace�hydraulic�power�pack (28,328.71) (22,155.88)

85,650,210.93 66,987,029.97Grand�Total



Order Order�Description 100%�Level SCE�Share800933319 2E089�Split�Stabilizer:�ASC�D0064420�and 17,731,766.84 13,868,014.85800842826 U3�:�3E088�ECT�&�Tube�Plugging(Feb�2012 3,801,064.07 2,972,812.21800589922 2E088�Eddy�Current�Testing�and�Tube�Plug 3,386,826.06 2,648,836.66800842830 U3�:�3E089�ECT�&�Tube�Plugging(Feb�2012 2,893,626.25 2,263,105.09800843405 U2�Direct�SGR�Work�DEO 1,848,356.11 1,445,599.31800589928 2E089�Eddy�Current�Testing�and�Tube�Plug 1,640,995.65 1,283,422.70800898942 AREVA�Engineering�support�activities 830,050.14 649,182.21800843403 U3�Forced�Direct�SGR�Work�DEO 556,186.75 434,993.66800847272 U2�Emergent�Work�U2SG088��Health�Physics 511,711.99 400,209.95800911398 U2�Return�to�Service�Steam�Generator�PMO 373,125.97 291,821.82800847273 U2�Emergent�Work�U2SG089��Health�Physics 346,453.81 270,961.52800884356 Sup�Order�Tracking�costs�for�Aux�Blr 339,298.85 265,365.63800857062 $$�U2�Direct�SGR�Work�NFM 294,031.80 229,962.27800911440 U3�Return�to�Service�Steam�Generator�PMO 181,408.44 141,879.54800840786 U3�Forced�Outage�Support��PMO�Division 159,609.85 124,830.86800840690 U3�Forced�Outage�Support��Work�Control 158,723.08 124,137.32800847266 U3�Forced�Outage�U3SG089��Health�Physics 141,191.10 110,425.56800921685 Phase�I�U2�Steam�Generator�Repair 133,163.19 104,146.93800869587 SET�UP�TO�"RECIRC"�THE�SECONDAY�COND.�SY 125,724.83 98,329.39800847482 OPS�Emergent�U2E088�S/G�work 121,103.95 94,715.40800840809 U3�Forced�Outage�U3SG088��Health�Physics 106,874.41 83,586.48800911510 2E089�ECT�and�plugs/stabilizers 104,164.88 81,467.35800845381 U3�Forced�Outage��PI�Support 96,035.00 75,108.97800847485 OPS�Emergent�U3E088�S/G�work 83,278.92 65,132.44800907819 U2�Open/Close�Equip�Hatch 78,616.11 61,485.66800847486 OPS�Emergent�U3E089�S/G�work 75,577.09 59,108.84800847487 OPS�Emergent�U2E089�S/G�work 74,281.47 58,095.54800928623 SGR_Team�Eng�Initiation 55,313.00 43,260.30800907137 Temp�Power�U2�Steam�Generator�Tube�Expan 49,771.89 38,926.60800911646 U2�SG�Phase�2�Eddy�current�scaffolds 46,167.28 36,107.43800842079 SSS�U3�Forced�Outage�Common�Costs�split 38,927.02 30,444.82800910082 Replace�hydraulic�power�pack 30,954.69 24,209.66800889200 MATERIAL�ONLY�for�AUX�Boiler 27,820.98 21,758.79800840785 U3�Forced�Outage�Support��Operations�Di 26,420.69 20,663.62800868171 Security�U2�SGR�Emergent�Work 25,802.47 20,180.11

Repairs




Repairs

800914347 Temp�Power�U3�Steam�Generator�Inspection 25,140.87 19,662.67800931933 U3�Layup�Team�Support 23,275.00 18,203.38800912755 Modify�existing�Security�Concealment�Bar 22,041.13 17,238.37800907136 Pen�34�flange/cable�temp�fixture 20,765.33 16,240.56800913792 Remove/Install�E089�Hot�and�Cold�Leg�Man 18,137.94 14,185.68800913787 Remove/Install�S31301ME088�HOT�and�COLD 17,615.68 13,777.22800840810 U3�Forced�Outage�U3SG088��Chemistry�Supp 17,532.24 13,711.96800923870 SGR�PH1��Relocate�SGR�Personnel 15,184.78 11,876.02800841295 Security�U3�Forced�Outage�2012 14,346.35 11,220.28800911786 Scaffold�E089�Eddy�Current�U3�SG�Phase�2 12,641.11 9,886.61800915050 U3�Pen�34�temp�service�head 10,480.13 8,196.51800840767 U3�Forced�Outage�Support��Maintenance�D 9,944.62 7,777.69800888101 Scaffold�support�for�the�installation�of 8,231.13 6,437.57800893229 Install;�piping�manifolds,�hoses,�and�co 7,807.31 6,106.10800901688 U3�Forced�Outage��Business�support.��Ch 6,511.42 5,092.58800901943 U2�SGR��BUSINESS�SUPPORT.��Charge�this 6,307.42 4,933.03800911989 2E088�ECT�and�plugs/stabilizers 6,069.72 4,747.13800847277 Emergent�Work�for�Maintenance�Division�a 5,721.89 4,475.09800850010 2E088�Camera�inspect�upper�tube�bundle 4,925.60 3,852.31800921686 Phase�I�U3�Steam�Generator�Repair 4,470.00 3,495.99800909676 Modify�Security�Concealment�Plates�at�85 4,319.19 3,378.04800842575 SUPPORT�ORDER�TO�OPEN/CLOSE�UNIT�3�EQUIP 4,317.92 3,377.05800873488 Unit�2�SG�Return�to�Service 4,043.34 3,162.30800932343 U3LU�Transfer�dry�lay�up�supply�air�to�R 3,879.00 3,033.77800916237 Install�U2�N16�Detector�Stands�(NECP) 3,575.45 2,796.36800947300 Scaffold�S31301MR283�Ops�Vent�Valve�(2L) 2,805.40 2,194.10800912703 Insulation�R/R.�3RN7871�1�Nozzle�inspect 2,745.34 2,147.13800928631 SGR_Team�Procurement�Initiation 2,561.16 2,003.08800918219 U2�SG�Emergent�Work��NBA�support�to�SG 2,381.17 1,862.31800921023 Common�Provide�Gen.�Areva�Supt 2,292.80 1,793.20800905313 Install�U2�N16�Gamma�Detect�Sys�(TECP) 2,264.88 1,771.36800864850 Replace�3PT0102�1�(10CFR21�Issue) 2,136.87 1,671.25800840830 U3�E088�direct�work�cost�collector�Force 2,048.64 1,602.24800927138 Reference�NN�202077510�3:�Remove�Ladder 2,011.37 1,573.09800842352 NTD�U3�Forced�Outage�Common�In�process�& 1,970.92 1,541.46




Repairs

800914400 Scaffold�E088�Eddy�Current�U3�SG�Phase�2 1,963.47 1,535.63800877417 Scaffold.�S31305MR302�Mach.�Vavle�Repl. 1,902.90 1,488.26800869589 Perform�dry�layup�for�point�heaters�and 1,876.27 1,467.43800911759 U2�SG�Phase�2�B&C�Insulator�support 1,677.60 1,312.05800928629 SGR_Team�Eng�Travel 1,156.48 904.48800943086 2E088�Split�Stabilizer:�ASC�D0065134 1,135.25 887.88800885508 Exercise�LP�Turbine�Valves 1,076.56 841.98800845843 2E089�upper�tube�bundle�camera�inspectio 840.70 657.51800916232 Sheet�Metal�Support�Per�NECP 828.60 648.05800847278 Emergent�Work�for�Maintenance�Division�a 746.41 583.77800842554 $$�U3�Forced�Outage�2012��NFM 700.00 547.47800867320 Turbine�vib�high�ann.�for�unknown�reason 692.52 541.62800911515 2XEF2�:�2E089��Remove�selected�plugs/sta 612.11 478.73800901206 Nozzle�Dam�Pre�installation�operational 482.61 377.45800870905 OP's�Scaffold�Dismantle.�Valves�(10L) 430.59 336.76800267306 FILL�AND�VENT�CTMT�XMTRS�/�SENS�LINES 430.00 336.30800913788 Install�and�Remove�NOZZLE�DAMS�in�Steam 421.67 329.79800249839 RESPONSE�TIME�TEST�3L035K724 344.00 269.04800927426 Install�covers�on�U3�Rx�Cavity�Clg�Fans. 340.86 266.59800607135 LINESTARTER�CLEAN,�INSPECT�AND�ADJUST 330.06 258.14800861088 Installation�of�U2�nozzle�dam�ME089P 297.08 232.35800861518 Installation�of�U2�nozzle�dam�ME088P 297.08 232.35800926727 Install�covers�on�U2�Rx�Cavity�Clg�Fans 253.10 197.95800913791 Install�and�Remove�NOZZLE�DAMS�in�Steam 180.67 141.30800921093 2XEF2�:�2E088�Remove�plugs�and�stabilize 167.06 130.66800881842 Install�/�Remove�Stop�Log 116.70 91.27800309442 MDR�PERIODIC�REPLACEMENT�AND�RESPONSE 86.00 67.26800511708 MDR�PERIODIC�REPLACEMENT�AND�RESPONSE�T 86.00 67.26800847480 WC�Emergent�U2E089�S/G�work 84.72 66.26800847484 WC�Emergent�U3089�S/G�work 47.80 37.38800082747 Replace�Flooding�Sensor�3LSH9467�2�(EQ) 24.51 19.17800809520 Light�bulb�over�heating�in�socket 7.15 5.59800841296 Access�Authorization�U3�Forced�Outage (56.56) (44.24)800911504 U2�Non�tie�in�Install/Remove�SG�Drain�Do (361.53) (282.75)800897108 Aux�Boiler/Pre�fab�&�Stage�Cables�in�PA (439.69) (343.88)




Repairs

800850553 3E089�and�3E088�Drain�down�Pump��Stage (638.22) (499.15)800857983 Install�Alternate�DLMS�Transducer (25,167.29) (19,683.34)800840831 Vendor�cost�collector�U3�SG�Forced�Otg�2 (264,347.02) (206,745.80)800840807 PEEP�Support�for�U3�unscheduled�outage (443,822.00) (347,113.19)800842686 U3�Forced�Direct�SGR�Work�PEEP (1,135,836.83) (888,337.98)

34,943,895.14 27,329,620.39Grand�Total


Appendix C

Unit�2

:�Incremen

tal�O

&M�fo

r�Steam

�Gen

erator�In

spectio

n�an

d�Re

pair�Ac

tivities

(2012�Re

corded

�Costs)

Functio

nal�G

roup

Order

Order�Descriptio

n100%

�Level

SCE�Share

Ope

ratio

ns80

0847

482OPS�Emergent�U2E08

8�S/G�work

568,66

2.20

444,75

0.71

��

8008

4748

7OPS�Emergent�U2E08

9�S/G�work

388,99

7.53

304,23

4.97

��

Ope

ratio

ns�Total

957,65

9.73

748,98

5.67

��

Mainten

ance

8006

0639

2LINESTA

RTER

�CLEAN

,�INSPEC

T�AN

D�AD

JUST

3,21

7.96

2,51

6.77

��

8006

0713

5LINESTA

RTER

�CLEAN

,�INSPEC

T�AN

D�AD

JUST

480.06

375.45

��

8006

7251

2Supp

ort��Carpe

nters�to�bu

ild�Scaffo

ld.

5,588.42

4,370.70

��

8008

4404

7Ope

n�2M

E089

�second

ary�manway(s)/Upp

er�bu

26,695

.02

20,878

.18

��

8008

4447

7Insulatio

n�S213

01ME089

�Secon

dary�m

/w�re

m85

6.99

670.25

��

8008

4447

9Scaffold:�W

orking�platform

2,50

6.93

1,96

0.67

��

8008

4727

7Em

ergent�W

ork�for�M

ainten

ance�Division

�a26

,350

.74

20,608

.91

��

8008

4727

8Em

ergent�W

ork�for�M

ainten

ance�Division

�a7,68

1.20

6,00

7.47

��

8008

4748

0WC�Em

ergent�U2E08

9�S/G�work

84.72

66.26

��

8008

4768

5R/R�2M

E088

�second

ary�manway(s)

19,583

.44

15,316

.21

��

8008

4812

5Scaffold:�W

orking�platform�E08

81,54

4.88

1,20

8.25

��

8008

5073

9Re

move/Re

install�handh

ole�covers�fo

r�ins

533.22

417.03

��

8008

5164

0Re

move/Re

install�handh

ole�covers�fo

r�ins

3,54

4.19

2,77

1.91

��

8008

5164

2Scaffold�E088�U�2�upp

er�handh

ole

5,863.27

4,585.66

��

8008

5164

3Re

move/Re

install�insulation

1,43

4.92

1,12

2.25

��

8008

5164

4Scaffold.�U

�2�M

E089�su

pport�u

ppe r�hand�h

13,466

.13

10,531

.86

��

8008

5164

5Re

move/Re

install�insulation�U�2

713.04

557.67

��

8008

5214

1Need�to�re

�ope

n�2E08

9�second

ary�manways

1,77

9.68

1,39

1.89

��

8008

6108

7Re

move/Re

install�90�de

g.�handh

ole�cover

35,716

.12

27,933

.58

��

8008

6108

8Installatio

n�of�U2�no

zzle�dam

�ME089

P3,07

3.06

2,40

3.44

��

8008

6151

8Installatio

n�of�U2�no

zzle�dam

�ME088

P3,05

1.38

2,38

6.48

��

8008

6259

7Install�new

�RDB

s�in�CP

Cs�A,B,C,D

178.92

139.93

��

8008

6491

1Prim

ary�scaffold�S21

301M

E088

�manways

8,14

2.41

6,36

8.18

��

8008

6525

9Scaffold�S21

301M

E089

�prim

ary�manways

11,151

.28

8,72

1.42

��

8008

6801

4Scaffold��shielding�U�2�Con

tainmen

t2,21

6.68

1,73

3.67

��

8008

7428

1Re

place�thrust�bearin

g�on

�2MP0

25.

17,176

.40

13,433

.66

��

8008

7449

3Provide�Temp�C�Pane

l7,54

5.33

5,90

1.20

��

8008

7756

7Co

rrect�Leaking�Boo

ster�Relay

280.98

219.75

�� Pr

epared

:�NB,�B&FS

C-1

Unit�2

:�Incremen

tal�O

&M�fo

r�Steam

�Gen

erator�In

spectio

n�an

d�Re

pair�Ac

tivities

(2012�Re

corded

�Costs)

Functio

nal�G

roup

Order

Order�Descriptio

n100%

�Level

SCE�Share

Mainten

ance

8008

7799

4Insulatio

n�S213

01ME088

�Secon

dary�M

an�W

ay2,10

4.00

1,64

5.54

��

8008

7811

3R/R�2M

E088

�second

ary�manway(s)

143.55

112.27

��

8008

7959

9Unit�2

�CEA

C�2�failure

929.01

726.58

��

8008

8016

2Scaffold.�2HV

5102

�B&C�Va

lve�Testing

4,21

7.40

3,29

8.43

��

8008

8539

3Po

wer�flush�pu

mp�inbo

ard�/�o

utbo

ard�be

ar14

7.80

115.59

��

8008

8550

1Exercise�LP�Turbine�Va

lves

322.29

252.06

��

8008

8816

3Scaffold.�2RN

7871

�1�I&

C�Inspect�N

ozzle

s3,42

4.22

2,67

8.08

��

8008

9109

8Re

move�/�R

eplace�SA1

312M

R171

297.69

232.82

��

8008

9209

6R/R�Insulatio

n.�SA1

312M

R171

�Rep

lacemen

t.1,79

6.45

1,40

5.00

��

8009

0120

6Nozzle

�Dam

�Pr e�in

stallatio

n�op

erational

(15,42

9.91

)(12,06

7.73

)��

8009

1151

52X

EF2�:�2E089

��Rem

ove�selected

�plugs/sta

612.11

478.73

��

8009

1499

9Re

move/Re

install�handh

ole�covers�fo

r�ins

78.17

61.14

��

Mainten

ance�Total

209,10

0.15

163,53

7.23

��

Engine

ering

8005

8992

22E08

8�Eddy�Current�Testin

g�and�Tube

�Plug

33,907

,711

.03

26,519

,220

.80

��

8005

8992

82E08

9�Eddy�Current�Testin

g�and�Tube

�Plug

1,94

1,94

1.16

1,51

8,79

2.18

��

8005

8993

1E089

�Divider�Plate�Ultrason

ic�Testin

g(585

.33)

(457

.79)

��

8006

9488

0Eddy�Current�Testin

g�Fibe

r�Optic�Cable�I

11,441

.53

8,94

8.42

��

8006

9488

1Pe

n34�for�S

/G�W

ork.�Rem

ove�&�Rep

lace�Pen

232.95

182.19

��

8008

4340

5U2�Direct�SGR�Work�DE

O9,61

1,58

2.80

7,51

7,21

8.91

��

8008

4340

6U2�Direct�SGR�Work�PEEP

31,250

.00

24,440

.63

��

8008

4394

4U2�:�2E089

�IN�SITU�Testin

g�U2C

17�Refue

l10

3,75

0.00

81,142

.88

��

8008

4584

32E089�up

per�tub

e�bu

ndle�cam

era�inspectio

0.01

0.01

��

8008

4623

02E08

9�second

ary�sid

e�fill�from�hose

36,781

.03

28,766

.44

��

8008

5001

02E08

8�Camera�inspect�u

pper�tu

be�bun

dle

22,604

.87

17,679

.27

��

8008

5089

52E08

9�2n

d�Camera�inspectio

n�of�se

con d

ary

34,858

.45

27,262

.79

��

8008

5161

4U2�E089

�"Upp

er�East"�(2

70�degree)�Hand�h

2,15

6.77

1,68

6.81

��

8008

5448

4U2�Pe

n�34

�supp

ort��sh

op�prefab

4,45

5.16

3,48

4.38

��

8008

5448

5U2:�Install�flange/cable�fixture�at�p

en6,49

5.12

5,07

9.83

��

8008

5706

2$$

�U2�Direct�SGR�Work�NFM

301,71

8.42

235,97

3.98

��

8008

5741

6U2�NFM

�T�Cold�Re

duction�Re

storation

9,20

0.03

7,19

5.34

��

8008

5913

2U2�DE

O�T�Cold�Re

duction�Re

storation

431.12

337.18

�� Pr

epared

:�NB,�B&FS

C-2

Unit�2

:�Incremen

tal�O

&M�fo

r�Steam

�Gen

erator�In

spectio

n�an

d�Re

pair�Ac

tivities

(2012�Re

corded

�Costs)

Functio

nal�G

roup

Order

Order�Descriptio

n100%

�Level

SCE�Share

Engine

ering

8008

6269

8Ve

ndor�cost�collector�U2�SG

�Forced�Outag

12,819

.00

10,025

.74

��

8008

6721

6Supp

ort�o

rder�to

�OPEN/CLO

SE�Unit�2

�Equ

ip34

,183

.71

26,735

.08

��

8008

7239

6Re

pair�U2�Pe

n�34

�temp�fla

nge/cable�seal

2,76

8.13

2,16

4.95

��

8008

7348

8Unit�2

�SG�Return�to�Service

303,36

2.20

237,25

9.58

��

8008

8435

6Sup�Order�Tracking�costs�for�Aux�Blr

1,56

9,71

3.24

1,22

7,67

2.73

��

8008

8792

1Tempo

rary�Auxiliary�Bo

iler�installatio

n9,05

4.27

7,08

1.34

��

8008

8810

1Scaffold�su

pport�for�th

e�installatio

n�o f

94,517

.61

73,922

.22

��

8008

8856

4Au

xBoiler�InsIall�road�plates/park�trail

46,862

.40

36,651

.08

��

8008

8882

0Fabricate�and�install�the

�requ

ired�Secur

31,646.98

24,751.10

��

8008

8920

0MAT

ERIAL�ONLY�fo

r�AUX�Bo

iler

280,82

7.28

219,63

5.02

��

8008

9060

62E088�Camera�inspect�u

pper�tu

be�bun

dle

6,31

0.30

4,93

5.29

��

8008

9322

9Install;�piping�m

anifo

lds,�hoses,�and

�co

45,720

.64

35,758

.11

��

8008

9516

4Au

x�Bo

iler�T

empw

r�Sup

port.�SWAP

�3BI27

�28

22,961

.42

17,958

.13

��

8008

9525

8Au

x�Bo

iler�T

est�T

empw

r�Sup

port

10,160

.28

7,94

6.35

��

8008

9710

8Au

x�Bo

iler/Pre�fab�&�Stage�Cables�in�PA

48,222

.05

37,714

.47

��

8008

9894

2AR

EVA�Engine

ering�supp

ort�a

ctivities

830,71

2.14

649,69

9.96

��

8009

0190

3Pre�Fab�Bo

iler�D

rain�Heade

rs25

,571

.36

19,999

.36

��

8009

0713

6Pe

n�34

�flange/cable�te

mp�fixture

28,367

.18

22,185

.97

��

8009

0713

7Temp�Po

wer�U2�Steam�Gen

erator�Tub

e�Expan

106,53

5.68

83,321

.56

��

8009

0781

9U2�Ope

n/Close�Equip�Ha

tch

131,32

0.93

102,70

6.10

��

8009

0967

6Mod

ify�Security

�Con

cealmen

t�Plates�a

t�85

10,316

.80

8,06

8.77

��

8009

1139

8U2�Re

turn�to

�Service�Steam

�Gen

erator�PMO

1,29

1,11

3.53

1,00

9,77

9.89

��

8009

1150

4U2�Non

�tie�in�Install/R

emove�SG

�Drain�Do

13,416

.22

10,492

.83

��

8009

1151

02E08

9�EC

T�and�plugs/stabilizers

881,94

7.23

689,77

0.93

��

8009

1164

5U2�SG

�Phase�2�HP�scaffold�su

pport

1,02

9.44

805.13

��

8009

1164

6U2�SG

�Phase�2�Edd

y�curren

t�scaffo

lds

100,22

8.66

78,388

.83

��

8009

1164

8U2�SG

�Phase�2�B&C�scaffolds�sup

port

3,01

7.38

2,35

9.89

��

8009

1175

9U2�SG

�Phase�2�B&C�Insulator�sup

port

4,50

9.36

3,52

6.77

��

8009

1198

92E08

8�EC

T�and�plugs/stabilizers

72,360

.76

56,593

.35

��

8009

1275

5Mod

ify�existing�Security�Co

ncealm

ent�B

ar22

,691

.65

17,747

.14

��

8009

2109

32X

EF2�:�2E088

�Rem

ove�plugs�a

nd�stabilize

389.03

304.26

�� Pr

epared

:�NB,�B&FS

C-3

Unit�2

:�Incremen

tal�O

&M�fo

r�Steam

�Gen

erator�In

spectio

n�an

d�Re

pair�Ac

tivities

(2012�Re

corded

�Costs)

Functio

nal�G

roup

Order

Order�Descriptio

n100%

�Level

SCE�Share

Engine

ering

8009

2672

7Install�covers�o

n�U2�Rx�Cavity

�Clg�Fans

253.10

197.95

��

8009

2742

6Install�covers�o

n�U3�Rx�Cavity

�Clg�Fans.

348.98

272.94

��

8009

3059

2Sensor�installatio

n�U2�Co

ntainm

ent��VLPM

385,78

3.32

301,72

1.13

��

8009

3059

3U2�Co

ntainm

ent��VLPM

S�Upgrade

�ASC�2

133,78

0.38

104,62

9.64

��

8009

3331

92E089�Split�Stabilizer:�A

SC�D00

6442

0�and

14,337

,415

.64

11,213

,292

.77

��

8009

3730

1U2�Carp/Insulator�VLPMS�Upgrade

�ASC2.

70,895

.92

55,447

.70

��

8009

4308

62E088�Split�Stabilizer:�A

SC�D00

6513

41,13

5.25

887.88

��

8009

5292

32X

EF2�:�2E088

�Sec�side

�PI NG�test��W

est�U

4,93

5.48

3,86

0.04

��

8009

5292

42X

EF2�:�2E089

�Sec�side

�PING�te

st��W

est�U

9,26

2.96

7,24

4.56

��

8009

5659

8Supp

ort�A

reva�fo

r�E08

8�/�E

089�Ha

nd�Hold

13,563

.03

10,607

.65

��

8009

6363

6Material�only�WO�to

�supp

ort�the

�AUX�Bo

il1,43

3.87

1,12

1.43

��

8009

8136

7VLPM

S�Upgrade

�O&M�re

lated�cost�to

�capita

624,00

0.00

488,03

0.40

��

Engine

ering�To

tal

67,651

,489

.91

52,910

,230

.26

��

RadC

hem�Con

trol

8008

4727

2U2�Em

ergent�W

ork�U2SG08

8��Health

�Physic

s1,81

1,91

7.87

1,41

7,10

0.97

��

8008

4727

3U2�Em

ergent�W

ork�U2SG08

9��Health

�Physic

s1,40

8,54

9.39

1,10

1,62

6.48

��

RadC

hem�Con

trol�Total

3,22

0,46

7.26

2,51

8,72

7.44

��

Regulatory�Affairs

8009

2224

8U2SG�Emergent�W

ork��N

RA�Sup

port

1,27

2,60

2.46

995,30

2.38

��

Regulatory�Affairs�Total

1,27

2,60

2.46

995,30

2.38

��

Security

8008

6444

0Security�Supp

ort�for�U2�S/G�Insp.

2,869.38

2,244.14

��

8008

6817

1Security�U2�SG

R�Em

ergent�W

ork

60,117

.32

47,017

.76

��

Security�To

tal

62,986

.70

49,261

.90

��

Nuclear�Sup

port

8008

4756

2SSS�U2�SG

�Emergent�Inspectio

ns�&�Rep

airs

107,99

5.62

84,463

.37

��

8008

8228

9U2�Em

ergent�W

ork�U2SG��P

I�Sup

port

180,08

1.67

140,84

1.87

��

8008

8229

8Unit�2

�Emergent�W

ork�U2SG��CN

O�Sup

port

1,00

0.00

782.10

��

8009

0194

3U2�SG

R��B

USINESS�SU

PPORT

.��Ch

arge�th

is28

,953

.42

22,644

.47

��

8009

1821

9U2�SG

�Emergent�W

ork��N

BA�su

pport�to�SG

2,58

0.42

2,01

8.15

��

8009

2168

5Ph

ase�I�U

2�Steam�Gen

erator�Rep

air�

2,45

1,19

3.70

1,91

7,07

8.59

��

8009

2168

5Ph

ase�I�U

2�Steam�Gen

erator�Rep

air

65,609

.05

51,312

.84

��

8009

2387

0SG

R�PH

1��R

elocate�SG

R�Pe

rson

nel�

302,70

8.72

236,74

8.49

��

8009

2387

0SG

R�PH

1��R

elocate�SG

R�Pe

rson

nel

59,348

.73

46,416

.64

��

8009

2862

3SG

R_Team

�Eng�In

itiation�

105,72

0.88

82,684

.30

��

Prep

ared

:�NB,�B&FS

C-4

Unit�2

:�Incremen

tal�O

&M�fo

r�Steam

�Gen

erator�In

spectio

n�an

d�Re

pair�Ac

tivities

(2012�Re

corded

�Costs)

Functio

nal�G

roup

Order

Order�Descriptio

n100%

�Level

SCE�Share

Nuclear�Sup

port

8009

2862

4SG

R_Team

�Eng�Plann

ing�&�Prep�

13,370

.00

10,456

.68

��

8009

2862

5SG

R_Team

�Eng�Training�&�Organiza

tional�D

1,99

2.83

1,55

8.59

��

8009

2862

8SG

R_Team

�Eng�Services�

25,677

.00

20,081

.98

��

8009

2862

8SG

R_Team

�Eng�Services

572.35

447.63

��

8009

2862

9SG

R_Team

�Eng�Travel�

4,15

6.48

3,25

0.78

��

8009

2863

1SG

R_Team

�Procuremen

t�Initiation�

7,53

2.14

5,89

0.89

��

8009

2863

3SG

R_Team

�Procuremen

t�Planning�&�Prep�

26,979

.49

21,100

.66

��

8009

2863

4SG

R_Team

�Procuremen

t�Training�&�Organiza

�1,96

0.48

1,53

3.29

��

8009

2863

4SG

R_Team

�Procuremen

t�Training�&�Organiza

22,307

.59

17,446

.77

��

8009

2863

5SG

R_Team

�Procuremen

t�Materials�

13,836

.00

10,821

.14

��

8009

2863

6SG

R_Team

�Procuremen

t�Services

4,73

5.96

3,70

3.99

��

8009

2863

8SG

R_Team

�Procuremen

t�Travel�

140.63

109.99

��

8009

2880

1SG

R_Team

�Con

struction�Initiation�

19,345

.00

15,129

.72

��

8009

2880

1SG

R_Team

�Con

struction�Initiation

2,49

7.68

1,95

3.44

��

8009

2880

3SG

R_Team

�Con

struction�Planning�&�Prep�

64,672

.70

50,580

.52

��

8009

2880

3SG

R_Team

�Con

struction�Planning�&�Prep

1,48

9.18

1,16

4.69

��

8009

2880

4SG

R_Team

�Con

struction�Training�&�Organiz�

1,914.00

1,496.94

��

8009

2880

4SG

R_Team

�Con

struction�Training�&�Organiz

757.69

592.59

��

8009

4297

7U2&

3�Re

turn�To�Service��Division

�Sup

port�

1,10

6,27

9.12

865,22

0.90

��

8009

4297

7U2&

3�Re

turn�To�Service��Division

�Sup

port

94,125

.68

73,615

.69

��

8009

4709

4U2�RT

S�Misc

�Expen

ses�F

ERC�52

4,�SG�Return�

4,45

6.87

3,48

5.72

��

8009

4709

4U2�RT

S�Misc

�Expen

ses�F

ERC�52

4,�SG�Return

112,38

5.58

87,896

.76

��

8009

5976

8SG

R_T2�Perform

�Laser�Scan�Of�U

2�Co

ntainm

�5,50

2.88

4,30

3.80

��

8009

5976

8SG

R_T2�Perform


2�Co

ntainm

1,41

7.71

1,10

8.79

��

Nuclear�Sup

port�Total

4,84

3,29

7.25

3,78

7,94

2.78

��

Grand

�Total

78,217

,603

.46

61,173

,987

.67

��

Prep

ared

:�NB,�B&FS

C-5

Unit�3

:�Incremen

tal�O

&M�fo

r�Steam

�Gen

erator�In

spectio

n�an

d�Re

pair�Ac

tivities

(2012�Re

corded

�Costs)

Functio

nal�G

roup

Order

Order�Descriptio

n100%

�Level

SCE�Share

Ope

ratio

ns800840785U3�Forced

�Outage�Supp

ort��Ope

ratio

ns�Di

344,330.60

269,300.96

��

800847485OPS�Emergent�U3E088�S/G�work

412,971.39

322,984.92

��

800847486OPS�Emergent�U3E089�S/G�work

354,214.72

277,031.33

��

8008505533E089�and�3E088�Drain�do

wn�Pu

mp��Stage

18,501.21

14,469.80

��

Ope

ratio

ns�Total

1,130,017.92

883,787.02

��

Mainten

ance

800082747Re

place�Floo

ding�Sen

sor�3

LSH9

467�2�(EQ)

15,771.47

12,334.87

��

800205998LEAD

�Align�Motor�Spo

ol,�B

ag�Seal,�Pu

mp�s

3,364.64

2,631.48

��

800249836RE

SPONSE�TIM

E�TEST�3L035K6

2433.96

26.56

��

800249839RE

SPONSE�TIM

E�TEST�3L035K7

241,385.89

1,083.90

��

800253623Paint�S

31305M

R123�and

�supp

orts

157.74

123.37

��

800267306FILL�AND�VE

NT�CTMT�XM

TRS�/�S

ENS�LINES

3,627.91

2,837.39

��

800279063De

feat�Personn

el�Hatch�interlo

cks(forced

5,553.17

4,343.13

��

800279103INSTALL/RE

MOVE

�PZR�VEN

T�RIGS

�AS�DIRE

CTE

1,927.73

1,507.68

��

800279112RE

MOVE

�AND�RE

INSTALL�PR

ESSU

RIZER�MAN

WAY

13,398.49

10,478.96

��

800279756JUMPER�ALM�CONTA

CTS�FO

R�DR

AIN�DOWN

1,446.52

1,131.32

��

800280858INSTALL�RC

S/RE

FUEL�CAV

ITY�WAT

ER�LEV

EL5,226.16

4,087.38

��

800281519GE

NER

AL�PAN

EL�IN

SPEC

TION

1,298.97

1,015.92

��

800281544GE

NER

AL�PAN

EL�IN

SPEC

TION

1,782.74

1,394.28

��

800282100CO

LD�CALIBRA

TE�TO�SUPP

ORT

�OPS

628.05

491.20

��

800282118CO

LD�CALIBRA

TE�TO�SUPP

ORT

�OPS

1,009.01

789.15

��

800283944Install�D

LMS�du

ring�OUTA

GES

2,035.65

1,592.08

��

800283945Perform�DLM

S�level�correlatio

ns�after�t

1,423.02

1,112.94

��

800283946RE

MOVE

�AND�RE

INSTALL�PR

ES.�m

anway�Ins.

1,974.34

1,544.13

��

800283947AN

NUAL�CER

TIFICA

TION�IN

SPEC

TION�AND�NDE

235.96

184.54

��

800283948INSTALL/RE

MOVE

�INSPEC

TION�PLATFORM

(Sky

1,057.57

827.13

��

800309442MDR

�PER

IODIC�RE

PLAC

EMEN

T�AN

D�RE

SPONSE

6,537.58

5,113.04

��

800334085UNIT�3�CNTM

T�EA

RLY�WAR

NING�FIRE

�DETECTI

3,056.96

2,390.85

��

800334142FO

3�UNIT�3�CNTM

T�AC

TUAT

ION�DETEC

TORS�SUR

502.35

392.89

��

800468031CO

LD�CALIBRA

TE�TO�SUPP

ORT

�OPS

3,440.86

2,691.10

��

800468034CO

LD�CALIBRA

TE�TO�SUPP

ORT

�OPS

1,048.74

820.22

��

800511708MDR

�PER

IODIC�RE

PLAC

EMEN

T�AN

D�RE

SPONSE�T

3,512.25

2,746.93

��

8005118743L035�K6

24�M

DR�Rep

lacemen

t1,816.01

1,420.30

��

8005274693H

V9302�MOVA

TS�Testin

g�&�PM

4,786.45

3,743.48

��

Prep

ared

:�NB,�B&FS

C-6

Unit�3

:�Incremen

tal�O

&M�fo

r�Steam

�Gen

erator�In

spectio

n�an

d�Re

pair�Ac

tivities

(2012�Re

corded

�Costs)

Functio

nal�G

roup

Order

Order�Descriptio

n100%

�Level

SCE�Share

Mainten

ance

800611033(LOOP)�PZR�PRE

SS�TO�PPS�CALIB

4,388.58

3,432.31

��

800621579(LOOP)�PZR�PRE

SS�TO�PPS�CALIB

4,795.28

3,750.39

��

800625228(LOOP)�PRE

SSURIZER�PR

ESS�(SMM�IN

PUT)

6,078.18

4,753.74

��

800625229(LOOP)�PRE

SSURIZER�PR

ESS�(SMM�IN

PUT)

2,794.40

2,185.50

��

800648227Perform�an�inspectio

n�of�im

pacting�"ham

m4,927.88

3,854.09

��

800665464FINAL�REPAIR��R

eplace�1"�g

ate�valve.

5,315.91

4,157.57

��

800672510S31201ME087�Scaffo

ld�Sup

port

5,309.83

4,152.82

��

800682176Weld��Final�re

pairs�on�flange

3,185.53

2,491.40

��

800683887Co

rrect�T

CBO�Reading�on�Re

corder

186.58

145.92

��

800692190Re

move�E089�Hot�and

�Cold�Leg�Manways.

1,827.99

1,429.67

��

800692198Re

move�S31301ME088�HOT�and�CO

LD�Leg�M

anw

65,444.62

51,184.24

��

800692652Co

ntingency�Install�3E088�Prim

ary�Manway

24,153.72

18,890.62

��

800693574Install�E089�Ho

t�and

�Cold�Leg�Manways

31,745.08

24,827.83

��

800700088Install�N

OZZLE�DAM

S�in�Steam

�Gen

erator

4,336.50

3,391.58

��

800700089Re

move�NOZZLE�DAM

S�from

�Steam

�Gen

erator.

145.05

113.44

��

800700090Install�N

OZZLE�DAM

S�in�Steam

�Gen

erator

3,543.18

2,771.12

��

800700091Re

move�NOZZLE�DAM

S�from

�Steam

�Gen

erator.

950.39

743.30

��

800734613Steam�Trap�Va

lve�Leakby

169.09

132.25

��

800750973Re

move�/�R

eplace�Roo

t�Valve

10,385.72

8,122.67

��

800751304Re

move�and�Re

place�socket�weld�un

ion.

3,529.76

2,760.63

��

800758720Weld_

�Final�re

pairs.�Two�valves

3,128.55

2,446.84

��

800769784Bu

ild�Scaffo

lding�to�access�P

IPING.

755.40

590.80

��

800776093DISA

BLE�DC

S�ALAR

MS�FO

R�OUTA

GE628.05

491.20

��

8007767833B

M39��Re

place�Ope

n/Close�Co

ntactor��S

2,682.79

2,098.21

��

800781948Ge

n�Brush�Ge

ar�Retrie

ve�Loo

se�Bolts�&�fo

1,026.70

802.98

��

800782212De

graded

�signal�cable

41.94

32.80

��

800784239Re

place�Electro�Hy

draulic�Con

troller

3,871.16

3,027.63

��

800784453Ve

rify�UA�Diff�Press�B

utton�in�SHO

P174.01

136.09

��

800809520Light�b

ulb�over�heatin

g�in�so

cket

89.66

70.12

��

8008126193P

�141�pum

p�packing�replacem

ent�a

nd�pum

p4,687.84

3,666.36

��

800821035Ope

n�and�clean�He

at�Exchanger.�Inspe

ct/r

4,047.64

3,165.66

��

800823358Re

move�and�Re

place�S31301MU880

860.39

672.91

��

800826320Re

place�Union

576.51

450.89

��

Prep

ared

:�NB,�B&FS

C-7

Unit�3

:�Incremen

tal�O

&M�fo

r�Steam

�Gen

erator�In

spectio

n�an

d�Re

pair�Ac

tivities

(2012�Re

corded

�Costs)

Functio

nal�G

roup

Order

Order�Descriptio

n100%

�Level

SCE�Share

Mainten

ance

800828080Inspect/Re

pair�Interio

r�S31203M

E001

2,822.68

2,207.62

��

800828081Install/R

emove�drain�do

wn�ho

ses.

1,722.72

1,347.34

��

800835434Scaffold�3HV

9302�M

OVA

TS�Testin

g9,205.97

7,199.99

��

800837151Perform�AOV�diagno

stic�te

sting

2,011.50

1,573.19

��

800840690U3�Forced

�Outage�Supp

ort��W

ork�Co

ntrol

571,743.55

447,160.63

��

800840767U3�Forced

�Outage�Supp

ort��M

ainten

ance�D

243,932.98

190,779.98

��

800840875Prep

are�Nozzle

�Dam

s�for�U3�Forced

�Outage

4,744.16

3,710.41

��

800840918Co

ntingent�W

O.�U

3:�3E088�Rem

ove/Re

instal

11,618.83

9,087.09

��

800841180Insulatio

n.�M

anway�Unit�3

�Forced�Outage

1,446.86

1,131.59

��

800841181Insulatio

n�Ha

ndho

ld�Unit�3

�Forced�Outage

2,886.58

2,257.59

��

800841250FW

�Bypass�3

HV1106�failed�op

en�on�RT

O5,993.18

4,687.27

��

800841344Inspect�a

nd�Rep

lace�Filters.

8,740.69

6,836.09

��

800841694U3�Re

move�insulatio

n�verify�mineral�woo

16,106.32

12,596.75

��

8008422913H

V4011�Re

set�Lim

it�Sw

itch

1,143.25

894.14

��

8008423283H

V9202,�Loo

p�2A

�charging�fail�to�close

6,078.65

4,754.11

��

800842590Co

rrect�S

ticking�Letdo

wn�Va

lve�Co

ntrol

186.58

145.92

��

800842611Unit�3

�scaffold�ra

mps�personn

el�hatch

11,746.43

9,186.88

��

800842779Scaffold�3HV

2704��V

alve��O

verhaul

6,491.89

5,077.31

��

800842930Trou

blesho

ot�heater�con

trol�problem

1,037.35

811.31

��

8008432663C

EA78�1�Interm

itten

t�Failure�Sup

port

569.01

445.02

��

800843300RE

JECT

1,287.50

1,006.95

��

800843301R3

C16�forced

�Rem

ove/Re

install�3HV

274�Ins

2,327.15

1,820.06

��

800843419Insulatio

n�S31301ME089�M

an�way�Rem

oval

1,418.94

1,109.75

��

800843427scaffold�at�U

3�Ctmt�C

ontrol�Point

6,198.58

4,847.91

��

800843648Scaffold.�Shield�Wall�Cavity�Drain�Line

6,241.35

4,881.36

��

800846550RE

MOVE

�/�RE

INSTALL�SECO

NDA

RY�M

ANWAY

S6,771.66

5,296.12

��

800846553Re

move/reinstall�secon

dary�m

anways�3

ME08

39,825.64

31,147.63

��

800846556Insulatio

n�S31301ME088�Secon

dary�m

/w�re

m1,294.00

1,012.04

��

800846557Scaffold�S31301M

E088�Gin�W

heels

3,043.77

2,380.53

��

800846563S31301ME089.�Insulation�Second

ary�Manway

524.64

410.32

��

800847308He

at�up�valve�bo

dy.

2,914.74

2,279.62

��

800847311R/R�Insulatio

n.�3HV

4011�heat�b

lanket�ins

661.22

517.14

��

800847314Scaffold.�3HV

4011�M

OVA

T�&�M

echanical

7,078.33

5,535.96

��

Prep

ared

:�NB,�B&FS

C-8

Unit�3

:�Incremen

tal�O

&M�fo

r�Steam

�Gen

erator�In

spectio

n�an

d�Re

pair�Ac

tivities

(2012�Re

corded

�Costs)

Functio

nal�G

roup

Order

Order�Descriptio

n100%

�Level

SCE�Share

Mainten

ance

800847483WC�Em

ergent�U3088�S/G�work

360.35

281.83

��

800847484WC�Em

ergent�U3089�S/G�work

1,289.34

1,008.39

��

800847541Em

ergent�W

ork�for�M

ainten

ance�Division

�a7,413.76

5,798.30

��

800847542Em

ergent�W

ork�for�M

ainten

ance�Division

�a7,043.22

5,508.50

��

800850727Re

move/Install�U

pper�hand�ho

le�cover.�27

3,558.96

2,783.46

��

800850880Scaffold�E088�U�3�upp

er�handh

ole

8,898.21

6,959.29

��

800850882Supp

ort�o

rder�to

�remove�and�reinstall�3M

7,192.87

5,625.54

��

800850883Scaffold.�S31301M

E089�su

pport

5,400.36

4,223.62

��

800850884Need�insulatio

n�removal/in

stallatio

n�to

3,160.74

2,472.01

��

800853211Perform�Visu

al�Inspectio

n�on

�S/G�Snu

bber

3,772.08

2,950.14

��

800853487Clean�the�motor�hou

sing�breathers.

150.31

117.56

��

8008536233D

105��M

CCB�Re

placem

ent�/�Testin

g2,798.23

2,188.50

��

8008536243D

304��M

CCB�Re

placem

ent�/�Testin

g1,342.37

1,049.87

��

8008540263H

V0299��D

eterm/Reterm�Target�R

ock

415.95

325.31

��

800855479De

term

ine�Status�of�C

onservator�Bladd

ers

2,336.78

1,827.60

��

800855604Broken

�Con

crete�on

�U3�MFW

�P�062�Sup

port

1,741.21

1,361.80

��

800855793Provide�Temp�C�Pane

l2,201.33

1,721.66

��

800856386Scaffold�Sup

port�fo

r�3XM

�Work(L3)

11,896.65

9,304.37

��

800857983Install�A

lternate�DL

MS�Transducer

25,644.27

20,056.38

��

800859777Insulator�S

uppo

rt:�R

emove�Insulatio

n�on

3,310.72

2,589.31

��

800859879Supp

ort,�remove�/�install�insulatio

n3,229.28

2,525.62

��

800860708Re

move/Re

install�3E088�90�de

g.�handh

ole

3,089.74

2,416.49

��

800860738Re

move�/�R

eplace�Insulatio

n2,451.91

1,917.64

��

800861089

�Scaffo

ld.�U

�3�M

E088�90�De

gree�H/H

11,076.72

8,663.10

��

800861090Insulatio

n�U�3�M

E088�Hand�ho

le�90�De

g.1,052.00

822.77

��

800862414Provide�Tech�Sup

port�fo

r�DCS�SMR

318.71

249.26

��

8008633323A

0403�162�Tim

er�Failed�SV

�on�As�Lefts

3,481.09

2,722.56

��

800864850Re

place�3P

T0102�1�(10C

FR21�Issue)

4,842.44

3,787.27

��

800866752CLEA

N,�INSPECT,�and

�REPAIR�TU

BE�LEA

KS4,120.40

3,222.56

��

800866753Paint.�S31203ME001�Inspectio

n.1,575.15

1,231.92

��

800867320Turbine�vib�high�ann

.�for�unkno

wn�reason

3,106.83

2,429.85

��

800869215Preven

tively�Cycle�Main�Turbine�LP�Vv's

218.60

170.97

��

800869587SET�UP�TO

�"REC

IRC"�THE

�SEC

ONDA

Y�CO

ND.�SY

408,037.06

319,125.78

��

Prep

ared

:�NB,�B&FS

C-9

Unit�3

:�Incremen

tal�O

&M�fo

r�Steam

�Gen

erator�In

spectio

n�an

d�Re

pair�Ac

tivities

(2012�Re

corded

�Costs)

Functio

nal�G

roup

Order

Order�Descriptio

n100%

�Level

SCE�Share

Mainten

ance

800869589Perform�dry�layup�for�p

oint�heaters�and

9,495.44

7,426.38

��

800870566Scaffold.�S31305M

U568�BLAN

K�flange.

5,898.78

4,613.44

��

800870905OP's�S

caffo

ld�Dism

antle

.�Valves�(10L)

25,504.34

19,946.94

��

800872043Re

move/Re

install,�and/or�Fabricate�insul

1,049.28

820.64

��

800873108

Divers��Supp

ort�to�investigate/repair

697.47

545.49

��


L368A�Welde

rs�Shim�Inst.

3,578.75

2,798.94

��

800876254Re

move�/�R

eplace�Valve�S31305M

R302

144.77

113.22

��

800877417Scaffold.�S31305M

R302�M

ach.�Vavle�Rep

l.3,985.28

3,116.89

��

800881842Install�/�Rem

ove�Stop

�Log

1,511.70

1,182.30

��

800882112Ha

ndrail.�S32126C

R014�M

achinists�S

uppt.

8,145.18

6,370.35

��

800882500remove/replace�turning�vane

(s)

6,902.21

5,398.22

��

8008826213W

B116�W

ater�Box�cleaning

970.90

759.34

��

800883301Scaffold.�3PC

V2883�Va

lve�Testing

2,664.59

2,083.98

��

800885508Exercise�LP�Turbine�Va

lves

1,279.69

1,000.85

��

800888162Scaffold.�3RN

7871�1�I&

C�Inspect�N

ozzle

s8,549.83

6,686.82

��

800890531HJTC

�Heater�F

use�Re

moval�&�Rep

lacemen

t135.82

106.22

��

800890532HJTC

�Heater�F

use�Re

moval�&�Rep

lacemen

t271.64

212.45

��

800891674RE

M/INST�RX�HE

AD�CED

M�RSPT�VLPM

�CAB

LES

13,163.83

10,295.43

��

800891675VE

NT�TH

E�CE

DMs

12,981.02

10,152.46

��

800905312INSTALL�UNIT�2�AMPTEK�N16�RMS

943.00

737.52

��

800905313Install�U

2�N16�Gam

ma�De

tect�Sys�(TEC

P)5,071.13

3,966.13

��

800910082Re

place�hydraulic�pow

er�pack

2,625.98

2,053.78

��

800912703Insulatio

n�R/R.�3RN

7871�1�Nozzle

�inspect

3,372.37

2,637.53

��

800913787Re

move/Install�S31301M

E088�HOT�and�CO

LD17,615.68

13,777.22

��

800913788Install�and

�Rem

ove�NOZZLE�DAM

S�in�Steam

421.67

329.79

��


�Rem

ove�NOZZLE�DAM

S�in�Steam

7,069.77

5,529.27

��

800913792Re

move/Install�E089�Ho

t�and

�Cold�Leg�Man

18,137.94

14,185.68

��

800914400Scaffold�E088�Eddy�Current�U3�SG

�Phase�2

2,000.89

1,564.90

��

800916230Fabricate�(2)�Stand

s�per�NEC

P2,186.79

1,710.29

��

800916232Sheet�M

etal�Sup

port�Per�NEC

P3,072.60

2,403.08

��

800916237Install�U

2�N16�Detector�S

tand

s�(NEC

P)3,575.45

2,796.36

��

800921023Co

mmon

�Provide

�Gen

.�Areva�Sup

t5,739.76

4,489.07

��

800924243Unanticipated

�Minor�Sup

port�M

ainten

ance

16,849.22

13,177.77

��

Prep

ared

:�NB,�B&FS

C-1

0

Unit�3

:�Incremen

tal�O

&M�fo

r�Steam

�Gen

erator�In

spectio

n�an

d�Re

pair�Ac

tivities

(2012�Re

corded

�Costs)

Functio

nal�G

roup

Order

Order�Descriptio

n100%

�Level

SCE�Share

Mainten

ance

800924246Ope

n/Close�Equip.�Hatch��U3�De

fuel

991.07

775.12

��

800924247RE

FUELING�TO

OL�PR

EPAR

ATION�FOR�U3�DE

FUEL

7,276.98

5,691.33

��

800924761Main�De

fuel�W

O,�RV�He

ad�ARE

A�Mainten

ance

6,586.24

5,151.10

��

800932337U3LU�/�De

gas/Re

gas�G

enerator

1,996.32

1,561.32

��

800932338U3LU�/�Take�m

onthly�PI�readings�o

f�rotor

1,069.99

836.84

��

800932343U3LU�Transfer�d

ry�lay�up

�supp

ly�air�to�R

15,516.00

12,135.06

��

800932349U3LU�/�Install�deh

umidifiers�o

n�LP�tu

rbi

827.65

647.31

��

800932440U3LU�/�Blow

�dow

n�gene

rator�w

inding,�vacu

3,325.39

2,600.79

��

800933085Scaffold.��3MV0

01�RX�He

ad��Supp

ort.

24,560.40

19,208.69

��

800933476Scaffold.�F3C

16�CNT�Re

fuel�Sup

port

12,946.04

10,125.10

��


R283�Ops�Ven

t�Valve�(2

L)2,812.55

2,199.70

��

8009473533G

001��P

rovide

�Tem

porary�Pow

er�to

�Deh

um1,258.77

984.48

��

800949895U3LU�Scaffo

ld��3M

G001��M

ach.�Gen

.��(6L)

12,140.45

9,495.05

��

800951296U3LU�Scaffo

ld,��3M

K002��B/C��su

pt.�(3L)

4,459.04

3,487.42

��

800951362Re

move�and�install�insulation�from

�MSR�m

511.36

399.93

��

800954832TB

03020310013�Pen�Seal

567.09

443.52

��

800958657Ch

eck/Ch

ange�filte

rs�fo

r�ren

ted�de

humidi

54,756.35

42,824.94

��


�remove�Nozzle

�Dam

s865,011.68

676,525.63

��

800964727Scaffold.��2R

E7889A

��I/C��install�N

16.

2,332.31

1,824.10

��

800967766Scaffold.��3ECC

S��NDE

�Weld�Inspect.�(4L)

15,369.16

12,020.22

��

Mainten

ance�Total

3,060,096.05

2,393,301.12

��

Engine

ering

800840786U3�Forced

�Outage�Supp

ort��PMO�Division

2,062,229.72

1,612,869.86

��

800840807PEEP�Sup

port�fo

r�U3�un

sche

duled�ou

tage

301,967.27

236,168.60

��

800840808DE

O�Sup

port�fo

r�U3�un

sche

duled�ou

tage

1,194.78

934.44

��

800840811U3�Force�Outage��H

U�and

�Indu

stria

l�Safe

799.09

624.97

��

800840830U3�E088�dire

ct�work�cost�collector�Force

74,180.20

58,016.33

��

800840831Ve

ndor�cost�collector�U3�SG

�Forced�Otg�2

28,570,095.74

22,344,671.88

��


E088�Handh

oles

56,860.62

44,470.69

��

800841957Unit�3

�Fiber�Optic�cable�installatio

n8,769.41

6,858.56

��

800841992U3:�3E088�N2�Test�m

anifo

ld(Feb

�2012�Forc

8,766.06

6,855.94

��

800842554$$�U3�Forced

�Outage�2012��NFM

298,991.85

233,841.53

��

800842575SU

PPORT

�ORD

ER�TO�OPEN/CLO

SE�UNIT�3�EQUIP

71,241.72

55,718.15

��

800842577Scaffold�U3�Pen.�34�Outsid

e�Co

ntainm

ent

5,646.64

4,416.24

��

Prep

ared

:�NB,�B&FS

C-1

1

Unit�3

:�Incremen

tal�O

&M�fo

r�Steam

�Gen

erator�In

spectio

n�an

d�Re

pair�Ac

tivities

(2012�Re

corded

�Costs)

Functio

nal�G

roup

Order

Order�Descriptio

n100%

�Level

SCE�Share

Engine

ering

800842578U3�Pen3

4�for�S

/G�W

ork.�Rem

ove�&�Rep

lace

11,148.79

8,719.47

��

800842674U3�tempo

rary�pow

er�fo

rced

�outage

86,814.80

67,897.86

��

800842686U3�Forced

�Dire

ct�SGR

�Work�PEEP

339,390.93

265,437.65

��

800842721U3�Scaffold�Pen

.�34�Insid

e�Co

ntainm

ent

10,957.25

8,569.67

��

800842826U3�:�3E088�ECT

�&�Tub

e�Plugging(Feb

�2012

3,801,064.07

2,972,812.21

��

800842827U3�:�3E088�Sec.�Side�FO

SAR�(Feb

�2012�For

(25.39)

(19.86)

��

800842830U3�:�3E089�ECT

�&�Tub

e�Plugging(Feb

�2012

2,510,575.00

1,963,520.71

��

800842846U3�:�3E088�N2�Pressure�Test�sup

port�(Feb

19,492.16

15,244.82

��

800843403U3�Forced

�Dire

ct�SGR

�Work�DE

O3,241,324.21

2,535,039.66

��


E089�Handh

oles

61,289.42

47,934.46

��

800845380U3�Forced

�Outage��N

OD�Supp

ort

13,168.58

10,299.15

��

800845641E&

TS�Sup

port�work�for�U

3�Forced

�Outage

448.96

351.13

��

800846427Perform�3E088�upp

er�tu

be�cam

era�inspecti

21,863.60

17,099.52

��

800849870"U

3�FO

RCED

�OUTA

GE"�P

rovide

�supp

ort�to�Op

5,903.63

4,617.23

��

800849874"U

3�FO

RCED

�OUTA

GE"�P

rovide

�supp

ort�to�OT

1,335.60

1,044.57

��

800850012U3�E089�cam

era�inspect�u

pper�tu

be�bun

dle

15,247.18

11,924.82

��

800850750F3C1

6B�Ops�Hydro�Tem

pwr�S

pt4,333.53

3,389.25

��

800850772U3�:�3E089,�"Upp

er�W

est"�Handh

ole�camera

6,472.12

5,061.85

��

800850773U3�:�3E088�"U

pper�East"�Handh

ole�camera

12,974.14

10,147.07

��

800854459Drain�U3�Steam�Gen

erators�to�FFCP

D17,961.38

14,047.60

��

800854526U3�Non

�WAR

�S/G�drain�activities

2,914.34

2,279.31

��

800859421$$�U3�Direct�SGR

�Work�NFM

77,808.41

60,853.96

��

800860515U3�:�3E088�"U

pper�W

est"�Handh

ole�camera

4,551.17

3,559.47

��

800911440U3�Re

turn�to

�Service�Steam

�Gen

erator�PMO

376,492.64

294,454.89

��

800911786Scaffold�E089�Eddy�Current�U3�SG

�Phase�2

18,222.76

14,252.02

��

800914347Temp�Po

wer�U3�Steam�Gen

erator�Inspectio

n44,588.87

34,872.96

��

800915050U3�Pen�34�te

mp�service�he

ad10,527.53

8,233.58

��

8009228913X

EF2�:�3E088�Tub

eshe

et�straightne

ss5,746.90

4,494.65

��

800925732Ba

se�Charge�WO�fo

r�U3�Re

actor�D

efue

l�Pro

137,042.90

107,181.25

��

800927138Re

ference�NN�202077510�3:�R

emove�Ladd

er6,823.93

5,337.00

��

800931933U3�Layup�Team

�Sup

port

81,112.50

63,438.09

��

800937520Supp

ort�S

G�Re

covery,�O

ffload�U3�Re

actor

824,381.35

644,748.65

��

Engine

ering�To

tal

43,232,696.36

33,812,291.82

��

Prep

ared

:�NB,�B&FS

C-1

2

Unit�3

:�Incremen

tal�O

&M�fo

r�Steam

�Gen

erator�In

spectio

n�an

d�Re

pair�Ac

tivities

(2012�Re

corded

�Costs)

Functio

nal�G

roup

Order

Order�Descriptio

n100%

�Level

SCE�Share

RadC

hem�Con

trol

800840809U3�Forced

�Outage�U3SG0

88��H

ealth

�Physic

s2,147,790.44

1,679,786.90

��

800840810U3�Forced

�Outage�U3SG0

88��C

hemistry�Sup

p141,219.63

110,447.87

��

800847266U3�Forced

�Outage�U3SG0

89��H

ealth

�Physic

s889,729.95

695,857.79

��

800939804U3�De

fueling�HP

�Sup

port

7,709.83

6,029.86

��

RadC

hem�Con

trol�Total

3,186,449.85

2,492,122.43

��

Regulatory�Affairs

800841770U3�Forced

�Outage��N

RA�Sup

port�2012

559,696.40

437,738.55

��

Regulatory�Affairs�Total

559,696.40

437,738.55

��

Security

800841295Security�U3�Forced

�Outage�2012

112,073.18

87,652.43

��

800841296Access�Autho

rization�U3�Forced

�Outage

12,904.01

10,092.23

��

Security�To

tal

124,977.19

97,744.66

��

Training

800842352NTD

�U3�Forced

�Outage�Co

mmon

�In�process�&

18,347.53

14,349.60

��

Training�Total

18,347.53

14,349.60

��

Nuclear�Sup

port

800841254U3�Forced

�Otg��B&

FS�su

pport��Charge

967.87

756.97

��

800841839U3�Forced

�Outage�Re

gulatory�Projects�sup

953.42

745.67

��

800842079SSS�U3�Forced

�Outage�Co

mmon

�Costs�sp

lit216,295.61

169,164.80

��

800843283MED

ICAL�U3�Forced

�Outage�Co

mmon

�costs�sp

4,409.79

3,448.90

��

800844771U3�Forced

�Outage��N

BA�su

pport�to�SG

�lea

20,652.24

16,152.12

��

800845381U3�Forced

�Outage��P

I�Sup

port

235,312.76

184,038.11

��

800845391U3�Forced

�Outage�IT�Com

p�&�Telecom

�Com

mo

12,816.14

10,023.50

��

800882299U3�SG

�Emergent�W

ork��CN

O�Sup

port

800.00

625.68

��

800901688U3�Forced

�Outage��B

usiness�sup

port.��Ch

27,093.42

21,189.76

��

800921686

Phase�I�U

3�Steam�Gen

erator�Rep

air�

37,213.39

29,104.59

��

800959769

SGR_

T3�Perform


3�Co

ntainm

�8,637.20

6,755.15

��

800959769SG

R_T3�Perform


3�Co

ntainm

4,618.57

3,612.18

��

Nuclear�Sup

port�Total

569,770.41

445,617.44

��

Grand

�Total

51,882,051.71

40,576,952.64

��

Prep

ared

:�NB,�B&FS

C-1

3

Appendix D

Func

tiona

l Gro

upC

ost E

lem

ent G

roup

Ve

ndor

Ord

er N

umbe

rO

rder

Des

crip

tion

Tota

lSu

m o

f Gra

nd T

otal

GR

C G

roup

ing

Cos

t Ele

men

t Gro

upVe

ndor

Ord

er n

umbe

rO

rder

Des

crip

tion

Tota

lO

pera

tions

Con

trac

t�

��

��

��

��

��

��

��

��

��

�80

0850

553

��

��

��

��

��

��

��

��

!�"��

#�$%

&�'�

()�*

CH

OIC

E W

OR

KFO

RC

E SO

LUTI

ON

S, L

LC T

otal

1,40

7.92

��

��

�+��

�,

��

��

��

��

��

��

��

��

8008

5055

3��

��

��

��

��

��

��

��

� !�

"��#�

$%&.

��'

)(*

STO

NE

& W

EBST

ER C

ON

STR

UC

TIO

N, I

NC

Tot

al16

,984

.72

Ope

ratio

ns T

otal

18,3

92.6

4M

aint

enan

ceC

ontr

act

/�

��

�:

:�

��

/��

��

��

�80

0905

312

��

�/

��

��*

�/:

��

��

&.�

:�

�'�)

��A

CS

CO

MM

UN

ICA

TIO

NS

INC

Tot

al94

3.00

/

�;�

�/

��

, �

��

�

<��

��

�80

0692

198

%

�=%�

��&

��&:

��

��

��

��

��

��

%$�:

��

.'�(

��).

.A

RIZ

ON

A P

UB

LIC

SER

VIC

E C

O T

otal

64,7

33.6

6,

/�

��

�/:

��

��

�

<��

��

��

8008

4069

0�

��

�>%�

��#

�$%�

��!

!��#�

"��

?��

��#��

@A&

&�'&

.)(�

BLA

CK

DIA

MO

ND

SER

VIC

ES IN

C T

otal

511,

416.

73�

��

��

��

��

��

��

��

��

��

�80

0249

839

�

��

��

��

��:

��

��

��

��A

(*'

&��

A)��

8002

6730

6��

�/

��

�<�

��

��:

��D

:�

��E�

��

��

� ��

��

&��'

()�'

8002

7975

6F�

:�

�

�/ :

��

��/

��

��

��

/

��

��

�&�

''.)

A*80

0280

858

��

�/

��

�E

��

� �

�/

<��

G��

/��

�

�<

�

��&�

()*�

8002

8154

4H

��

�

/ �

�/

��

��

��

��

��

�&�

A�.)

&.80

0309

442

:�

��

�

��

��

��

/�

�:

��

��/

��

��

��

��

��

��.�

�)�*

8004

6803

1�

� �

"�/

�,

/

��

��

��

��

��

��

�*�

�&*)

�&80

0468

034

��

�"�

/ �

,

/��

��

��

��

�

��

��

.*.)

��80

0511

708

:�

��

�

��

��

��

/�

�:

��

��/

��

��

��

��

��

��&�

AA()

��80

0511

874

� ��

A"

.*'�

:�

�

%!@�

>%

%�#

A&.)

��80

0625

228

I �

��

J��

��

��

�;

�

��

��

��I�

::

��

��J

��

&)*�

8007

7678

3�,

:��

�"�

%!@�

>%��

!%�E

�@�

K%��

��#�

>#��

�"��

&�.�

�)��

8008

4076

7�

��

�>%�

��#

�$%�

��!

!��#�

"�:��

�#%�

��>%

��&�

�*&.

)��

8008

6333

2�/

�'��

�&.*

��

%��

��@%

��

<��

��/

K" %

L#K&�

�(*)

'&80

0891

674

�

:E��

��

D

��

/�

��

�:

"�

��"

< �

:��

/,

��

&��&

')��

8008

9167

5<

��

��

��

��

:K

.�*)

*AC

HO

ICE

WO

RK

FOR

CE

SOLU

TIO

NS,

LLC

Tot

al46

,137

.08

�

/�

��

��

�/

��

�80

0527

469

��<

��*

�:�

</

��

%K#��

$�+

��:

'�(�

.)'A

8006

9265

2�

��#��

$%�>

M��

K#�@

@��

��

��

��M�

:��

��M

&��

')��

8008

4229

1��

<'�

&&�

%K%#

� �

�#��

��#>

N&�

&'�)

*A80

0842

328

��<

�*�*

��

!�*/

�>N�

�$��

$�L�

�@�#�

�>@�

K%.�

�(�)

.A80

0843

300

�

F��

�&�

*�()

A�80

0846

550

�

:�

<�

�E�

��

��/

��

��

��

�/

G

�:/

��

/G

�A*

')��

CR

AN

E N

UC

LEA

R IN

C T

otal

14,9

04.6

5H

�/

��

� �

/

��/

��

��G

��

<

��

�80

0840

690

��

��>

%��

�#�$

%��

�!!�

�#�"��

��?�

��

#��@

'&*)

(&G

CA

NU

CLE

AR

FA

CIL

ITY

SER

VIC

ES T

otal

412.

71�

��

��

�

��

<�

��

:�

��/

��

�)

8009

2476

1:

��

�%L

�%@��

��

<��

%��

/

�/

�:��

�#%�

��>%

��)�

.N

EW W

OR

LD E

NVI

RO

NM

ENTA

L, IN

C. T

otal

38.9

6�

��

��+

��

,�

��

��

��

��

��

��

��

�80

0283

946

�

:�

<�

�/�

��

��

��/

��

�

�)�

��

�M��

K)&�

�(')

�'80

0665

464

��

/ �

�

�/

��"�

%!

@�>%

�&O�$

�#%�

=�@=

%)'�

�*A)

'�80

0672

510

��&

*�&:

��

(��

>�LL�

@��

�!!�

�#A�

��)

��80

0672

512

��!

!��#�

"��

!%�#

%�K�

#��P

��@�

��>�

LL�@�

)A�

A��)

'*80

0700

088

��K#

�@@��

�;;

��

/:

��

��#%

� �H

%�%�

�#��

*�'&

&)(�

8007

0009

0��

K#�@

@��

;; �

��/

:�

��

#%�

�H%�

%��#

��*�

'A�)

'*80

0750

973

%

�=%�

E�%!

@�>%

��

#�<�@

=%&�

�&.�

)��

8007

5872

0�

%@�Q

��

�@��%

!��K

)��

��=�

@=%K

*�.�

�).�

8007

6978

4,

��@�

��>�

LL�@�

��$�

#��

>>%K

K��

��

H)

(AA)

'�80

0835

434

�>�

LL�@�

��

<��

�*�:

�<

/��

��%K

#��$

��*�

A)�(

8008

4076

7�

��

�>%�

��#

�$%�

��!

!��#�

"�:��

�#%�

��>%

��(�

�('*

)*.

8008

4118

0��

K�@�

#��)

�:��

��M

��

#��

��>%

��

�#�$

%&�

''.)

�.

Con

trac

tors

and

Con

sulta

nts

Supp

ortin

g St

eam

Gen

erat

or In

spec

tion

and

Rep

air A

ctiv

ities

(201

2 $,

100

% L

evel

)

�"&

��%

!��%

�R��

,��,

+��

Func

tiona

l Gro

upC

ost E

lem

ent G

roup

Ve

ndor

Ord

er N

umbe

rO

rder

Des

crip

tion

Tota

l

Con

trac

tors

and

Con

sulta

nts

Supp

ortin

g St

eam

Gen

erat

or In

spec

tion

and

Rep

air A

ctiv

ities

(201

2 $,

100

% L

evel

)

Mai

nten

ance

Con

trac

t�

��

��+

��

,�

��

��

��

��

��

��

��

�80

0841

181

��K�

@�#��

��

��N

�@��

��

#��

��>%

��

�#�$

%*�

��.)

A�80

0841

694

��

%

�=%�

��K�

@�#��

��=%

��LM�

��

%��@

��

&�A�

�)�*

8008

4261

1�

��#��

�K>�

LL�@�

��

!K�!

%�K�

��%@

�N�#

>N&&

�('.

)'�

8008

4277

9�

>�LL�

@��

�<

*(�'

��<�@

=%��

=%�N

��@

.�'�

&)��

8008

4330

1

��&.

�L��>

%��

% �=

%E

%��K

#�@@�

��<

*('�

��K

*��*

()&A

8008

4341

9��

K�@�

#��

��&

��&:

��

��:

��

�M�

% �=

�@&�

'&�)

�'80

0843

427

K>�L

L�@�

��#��

��

# #��

��#��

@��

�#A�

��)

(A80

0843

648

�>�

LL�@�

)��N�

%@��

��@

@��=

�#M��

��

� ��

%.�

*'&)

�A80

0844

479

�>�

LL�@�

R��

?��$

�!@�

#L��

*�A�

.)��

8008

4655

6��

K�@�

#��

��&

��&:

��

��

%>��

��M

� E�

��%

&�*�

()��

8008

4655

7�

>�LL�

@��

�&��

&:�

��

H��

��N%

%@K

��&

A)(.

8008

4656

3�

�&��

&:�

��)

��K�

@�#��

��

%>��

��M

�:��

��M

A*')

.'80

0847

277

�

%�$%

�#��

��?�

L��:

��#

%��

>%��

�=�K

��

��

'.')

.�80

0847

278

�

%�$%

�#��

��?�

L��:

��#

%��

>%��

�=�K

��

��

(��)

(�80

0847

308

�%�

#��!�

=�@=

%�P�

�M)

*��&

')('

8008

4731

1

E��

K�@�

#��)

��

<'�

&&�N

%�#�P

@��?

%#��

K..

&)**

8008

4731

4�

>�LL�

@�)��

�<

'�&&

�:�

</

��+

�:%>

N��

>�@

(��(

�)��

8008

4754

1�

%�

$%�#

��

?�L�

��:��

�#%�

��>%

��=

�K��

��

'��&

()�&

8008

4754

2�

%�

$%�#

��

?�L�

��:��

�#%�

��>%

��=

�K��

��

'�'A

�)�'

8008

4812

5�

>�LL�

@�R��

��?�

�$�!

@�#L�

� ��

��

&�A'

')��

8008

5088

0�

>�LL�

@��

��

�"�

��!!

%��N

��N

�@%

��

�)*&

8008

5088

3�

>�LL�

@�)��

�&��

&:�

��

K�!!

��#

A�'�

�)�.

8008

5088

4�

%%��

��K�

@�#��

��%

�=

�@E��

K#�@

@�#��

��#�

&�'&

.)A*

8008

5164

2�

>�LL�

@��

��

�"*

��!!

%��N

��N

�@%

'�(�

�)'A

8008

5164

3

% �=

%E

%��K

#�@@�

��K�

@�#��

�&�

'�')

�*80

0851

644

�>�

LL�@�

)��"*

�:�

��

K�!!

��#��

!!%�

�N��

��N

&��'

..)&

�80

0851

645

%

�=%E

%�

�K#�

@@��

K�@�

#��

�"*

(&�)

�'80

0855

604

,��

?%��

��

>�%#

%��

��

:��

��"�

.*��

�!!�

�#&�

('&)

*&80

0855

793

��

=��%

��%

!��

"��

%@*�

*�&)

��80

0856

386

�>�

LL�@�

��!

!��#�

L��

D:

��

?I �

J&&

��.

).A

8008

5977

7��

K�@�

#��

�!!�

�#R�

% �=

%��

K�@�

#��

��

�&�)

(*80

0859

879

��!

!��#�

��%

�=%�

E��K

#�@@�

��K�

@�#��

��

**�)

*�80

0860

738

%

�=%�

E�%!

@�>%

��K�

@�#��

�*�

'A&)

�&80

0861

089

��>�

LL�@�

)��"�

�:�

��

��

%$�%

%��

E�&�

�(.�

)��

8008

6109

0��

K�@�

#��

�"�

�:�

��

��

��N�

@%��

��

%$)

&��A

*)��

8008

6491

1�

��

M�K>

�LL�

@��

*&��

&:�

��

��

��M

K��

&'*)

'&80

0865

259

�>�

LL�@�

��*&

��&:

��

��!�

� ��

M�

��

�MK

&&�&

A&)*

�80

0868

014

�>�

LL�@�

��KN�

%@��

�$��

"*��

��#�

��

%�#

*�*&

.).�

8008

7056

6�

>�LL�

@�)��

�&��

A:�

A.��

, /

�

�L@��

$%)

A��

�)(�

8008

7090

5�

�SK

��>�

LL�@�

��K

��

#@%)�<

�@=%

K�I&

� J

*A��

(�)(

A80

0872

043

%

�=%E

%�

�K#�

@@��

��E�

��P

��>�#

%��

K�@

&��'

�)*�

8008

7449

3�

��=�

�%��

% !�

�"�

��%@

(�'.

A)''

8008

7523

7�

>�LL�

@��

�&'&

A: �

.�/

��%@

�%�K

��N�

��

K#)

��A(

�)(A

8008

7741

7�

>�LL�

@�)��

�&��

A:

��*�

:�>

N)�<

�=@%

�%!

@)��

��A)

*�80

0877

994

��K�

@�#��

��

*&��

&:�

��

�%>

��

�M�:

��

�M*�

&�')

��80

0880

162

�>�

LL�@�

)�*�

<A&

�*�,

+�

�<�@

=%��

%K#��

$'�

*&()

'�80

0882

112

��

��

@)��

�*&*

.�

�&'�

:�>

N��

K#K�

��!

!#)

��&'

A)&�

8008

8330

1�

>�LL�

@�)��

��

<*�

��<

�@=%

��%K

#��$

*�..

')A�

8008

8816

2�

>�LL�

@�)��

�

(�(&

"&��+

��

K!%>

#��T

T@%K

��A'

�)��

8008

8816

3�

>�LL�

@�)�*

�

(�(&

"&��+

��

K!%>

#��T

T@%K

��'*

')**

8008

9167

4

�:

E��

��

D��

�/

��

��

:"

��

�"<

�:

��/

, �

�(�

.��)

A�80

0891

675

<�

��

��

��

�:

K��

A�A)

*.80

0892

096

E

��K�

@�#��

�)��

/&�

&*:

&(

&�

%!@�

>%

%�#)

&�(�

.)'A

�"*

��%

!��%

�R��

,��,

+��

Func

tiona

l Gro

upC

ost E

lem

ent G

roup

Ve

ndor

Ord

er N

umbe

rO

rder

Des

crip

tion

Tota

l

Con

trac

tors

and

Con

sulta

nts

Supp

ortin

g St

eam

Gen

erat

or In

spec

tion

and

Rep

air A

ctiv

ities

(201

2 $,

100

% L

evel

)

Mai

nten

ance

Con

trac

t�

��

��+

��

,�

��

��

��

��

��

��

��

�80

0912

703

��K�

@�#��

��

E)��

�

(�(&

"&��

�TT@

%��

K!%>

#��

�(*)

�(80

0914

400

�>�

LL�@�

��

��

��M�

��

�%�#

��

�H

��N�

K%�*

*��

�)��

8009

1623

2�

N%%#

�:%#

�@��

�!!�

�#��

%��

��

�*�

*'')

��80

0916

237

��K#

�@@��

*��

&.��

%#%>

#��

#��

K�I�

��

�J

��A(

A)'A

8009

2102

3�

�

��

��=�

�%�H

%�)�/

�%=�

��!

#��

�A&)

(�80

0924

246

�!%

�E�

@�K%

��U�

�!)��

�#>N

�"��

��

%L�%

@��

&)�(

8009

3308

5�

>�LL�

@�)��

��:

<��

&�

D��

%��

��!

!��#)

*'�A

.�)'

�80

0933

476

�>�

LL�@�

)��

&.��

��

%L

�%@��

�!!�

�#&*

��'.

)�'

8009

4730

0�

>�LL�

@��

�&��

&:

*��

�!K

�<%�

#�<�@

=%�I*

J*�

�&*)

AA80

0949

895

��

��

>�LL�

@��

�:H

��&�

�:�>

N)�H

%�)��

I. J

&*�&

'�)'

A80

0951

296

��

��

>�LL�

@��

�:

��*�

��,E�

��K�!

#)�I�

J'�

'A�)

�'80

0951

362

%

�=%�

��

��K#

�@@��

�K�@

�#��

��L��

�:

�

� A&

&)�.

8009

5483

2�,

��*

��&�

�&��

�%�

��%�

@A.

()��

8009

6472

7�

>�LL�

@�)��

*�

(��

/��

E��

��K#

�@@��

&.)

*��

*)�&

8009

6776

6�

>�LL�

@�)��

��

��

��

��

%@��

��K!

%>#)�

I' J

&��

(�)A

.ST

ON

E &

WEB

STER

CO

NST

RU

CTI

ON

, IN

C T

otal

470,

810.

59��

/:

��

��

��/

��

�

<��

��

��

)80

0751

304

%

�=%�

��

%!

@�>%

�K�>

?%#��

%@��

��

�)�(

A)��

TEA

M IN

DU

STR

IAL

SER

VIC

ES IN

C. T

otal

875.

00�

G �

� /

,�

/

��

��

��

8008

5321

1�

%�L�

� �<

�K��

@��K

!%>#

��

��

EH��

��PP

%��

((*)

��W

YLE

LAB

OR

ATO

RIE

S IN

C T

otal

3,77

2.08

G�

�

��

/,

8008

8184

2��

K#�@

@�E�

% �=

%��

#�!�

�$

*��)

(�YE

LLO

W C

AB

Tot

al20

3.70

Mai

nten

ance

Tot

al1,

114,

248.

16En

gine

erin

gC

ontr

act

/�

��

�:

:�

��

/��

��

��

�80

0694

880

��

M��

��%

�#��

%K#��

$��

P%��

!#�>

��P

@%��

*'�)

��A

CS

CO

MM

UN

ICA

TIO

NS

INC

Tot

al24

0.00

/�

/��

��

��

�/

��

�/

��

�80

0840

831

<%�

��>

�K#�>

�@@%

>#��

��

�H

��

>%��

�#$

�*.�

A��

�)��

8008

4394

4�

*�R�*

��

��

"��

��

%K#��

$��

*�&(

�%L

�%@

&��

(A�)

��A

NA

TEC

INTE

RN

ATI

ON

AL

INC

Tot

al73

8,75

0.00

/�

��

�/

��/

�

8009

2573

2,

�K%�

�N�

�$%�

��

�L��

��

%�>#

��

%L�%

@��

.*�.

�A)�

�80

0937

520

��!

!��#�

�H

�%>

�=%�

M��

LL@��

��

��

%�>#

��&�

'��.

.)*A

APS

USA

STA

RS

Tota

l25

6,67

1.25

/

�<

/��

�80

0589

922

*��

��

��M�

��

�%�#

��%K

#��$�

��

��P%

��@�

$�&

�'(�

��A�

)A�

8008

4078

6�

��

�>%�

��#

�$%�

��!

!��#�

"��:

��

�=�K

��

�)��

8008

4083

1<

%��

��>�K

#�>�@

@%>#

��

��

H��

��>%

��

#$�*

*(��

&��.

.�)*

�80

0843

403

��

��>

%��

��%>#

��H

��

��?�

��

�&�

&*&�

��)

''80

0843

405

�*�

��%

>#��

H

��

?��

��

'�'*

'��&

�)��

8008

5706

2VV

��*�

��%

>#��

H

��

?��

�:.�

��&

)��

8008

9894

2/

�

</

��$

��%%

��$�

K�!!

��#��

>#�=

�#�%K

�*.�

�&�)

��80

0933

319

*��

��

!@�#�

�#�

P�@�T

%�R�/

��

��

.''*

��

�&�

�'(�

�A*�

)��

AR

EVA

NP

Tota

l76

,305

,285

.93

,/

�

��

��

� �

/

��

8005

8992

2*�

��

��

M��

��%

�#��

%K#��

$��

��

P%��

@�$

*��

A&()

�A80

0589

928

*��

��

��M�

��

�%�#

��%K

#��$�

��

��P%

��@�

$*&

(�('

�)�A

8009

3059

2�

%�K�

��K

#�@@�

#��

�*�

��

#��

%�

#��<

�:

&��

AA).

�80

0930

593

�*�

��

#��

%�

#��<

�:

��

!$��

�%�/

��

�***

�.&�

)(*

BA

RTL

ETT

NU

CLE

AR

INC

Tot

al48

8,92

9.80

, /

�

��/

:�

��

��

<

��

��

�80

0840

786

��

��>

%��

�#�$

%��

�!!�

�#�"��

:�

��=

�K��

�&&

*�&�

*)��

8008

4083

1<

%��

��>�K

#�>�@

@%>#

��

��

H��

��>%

��

#$�*

&��

*�)�

�80

0842

686

��

��>

%��

��%>#

��H

��

��?�

��

��

&�A�

��&)

(A80

0843

403

��

��>

%��

��%>#

��H

��

��?�

��

�A�

�'&�

)*A

8008

4340

5�

*��

��%>#

��H

��

��?�

��

�(�

�'��

)*A

8008

8435

6�

�!��

��%�

"��

>?��

$�>�

K#K�

L��/

�W�,

@�&.

'�(�

�)&.

8009

1139

8�

*�

%#��

��#�

��%�

=�>%

��#%

� �H

%�%�

�#��

��:

��

��'

)A�

8009

3059

2�

%�K�

��K

#�@@�

#��

�*�

��

#��

%�

#��<

�:

��'�

A)��

�"�

��%

!��%

�R��

,��,

+��

Func

tiona

l Gro

upC

ost E

lem

ent G

roup

Ve

ndor

Ord

er N

umbe

rO

rder

Des

crip

tion

Tota

l

Con

trac

tors

and

Con

sulta

nts

Supp

ortin

g St

eam

Gen

erat

or In

spec

tion

and

Rep

air A

ctiv

ities

(201

2 $,

100

% L

evel

)

Engi

neer

ing

Con

trac

t,

/�

��

�/:

��

��

�

<��

��

��

8009

3059

3�

*��

��#�

��

%�#��

< �

:�

��!$

��%

�/�

��*

&*�(

.()�

�80

0931

933

��

�M�

!��%

� ��

�!!�

�#�&

�&&*

)A�

BLA

CK

DIA

MO

ND

SER

VIC

ES IN

C T

otal

751,

136.

41�

��

�<�,

/

��

��

�

��

��

��

)80

0843

405

�*�

��%

>#��

H

��

?��

��

��)

��C

EC V

IBR

ATI

ON

PR

OD

UC

TS IN

C. T

otal

900.

00�

��

��

��

��

��

��

��

��

��

�80

0589

922

*��

��

��M�

��

�%�#

��%K

#��$�

��

��P%

��@�

$&(

(�*�

&)�A

8005

8992

8*�

��

��

M��

��%

�#��

%K#��

$��

��

P%��

@�$

��A

'&)�

'80

0840

786

��

��>

%��

�#�$

%��

�!!�

�#�"��

:�

��=

�K��

�.�

&�'�

�).A

8008

4083

0�

��

��

��%

>#��

��?�

>�K#

�>�@

@%>#

��

��>%

.��'

��)(

*80

0841

957

��

#��

�P%�

��!#

�>�>

�P@%

��K#

�@@�

#��

.�()

*.80

0842

846

��

R��

��

�*�

��%

KK��

%��%

K#�K

�!!�

�#�I�

%PA&

*)&.

8008

4987

0O�

��

�

��

��

�/H

�O��

��=�

�%�K

�!!�

�#�#�

��!

&�'�

�)*'

8008

4987

4O�

��

�

��

��

�/H

�O��

��=�

�%�K

�!!�

�#�#�

��

&��

A).�

8008

5001

0*�

��

��

%��

��K!

%>#��

!!%�

�#�P%

�P��

�@%

&�(�

()*�

8008

5448

5�

*R��

K#�@

@�L@�

�$%E

>�P@

%�L�W

#��%

��#�!

%�'�

�)��

8008

8435

6�

�!��

��%�

"��

>?��

$�>�

K#K�

L��/

�W�,

@�&&

'�.&

.)(A

8008

9060

6*�

��

��

%��

��K!

%>#��

!!%�

�#�P%

�P��

�@%

*��'

')�*

8008

9525

8/

�W�,

��@%

��%K

#��%

!��

�!!�

�#��

�&.)

'�80

0901

903

��%

"��P

�,��

@%��

��

��%�

�%�K

&��

�)�*

8009

0713

7�%

!�

��

%��

*��

#%�

�H%�

%��#

��

�P%�

�W!

��*�

(�&)

A*80

0911

398

�*�

%#

��

#��

%�=�

>%��

#%�

�H%�

%��#

��

:�

�.(�

(&*)

.�80

0911

440

��

%#

��

#��

%�=�

>%��

#%�

�H%�

%��#

��

:�

&&&�

��)

��80

0925

732

,�K

%��

N��$

%��

��L�

��

%�

>#��

��%L

�%@��

��

�AA)

��80

0930

592

�%�

K��

�K#�

@@�#��

��

*��

��#�

��

%�#��

< �

:A�

(.&)

��80

0930

593

�*�

��

#��

%�

#��<

�:

��

!$��

�%�/

��

�*.�

'(�)

'�80

0937

520

��!

!��#�

�H

�%>

�=%�

M��

LL@��

��

��

%�>#

��A�

�*.�

)��

8009

5659

8�

�!!�

�#�/

�%=�

�L��

��

E��

��

��

��@

�&*

��'&

)A�

CH

OIC

E W

OR

KFO

RC

E SO

LUTI

ON

S, L

LC T

otal

1,64

4,94

7.12

��

� �

��

��

��

<

��

��

��

8008

4080

7�

��

��

�!!�

�#�L�

��

��K>

N%��

@%��

��#�

$%&�

��*

.)A�

8008

4340

3�

��

�>%�

��%

>#��

H

��

?��

��

(��'

��)�

�80

0843

405

�*�

��%

>#��

H

��

?��

��

''*�

'(�)

��C

IRC

LE W

OO

D S

ERVI

CES

, IN

C T

otal

693,

786.

50�

��

��

��

:��

G�

/:

��

��

�80

0840

831

<%�

��>

�K#�>

�@@%

>#��

��

�H

��

>%��

�#$

�*��

��

)��

CO

NTI

NU

UM

DYN

AM

ICS,

INC

Tot

al30

,000

.00

��

�

�H �

,/

��

��

��

�H

��

��

8008

8435

6�

�!��

��%�

"��

>?��

$�>�

K#K�

L��/

�W�,

@�&*

��*�

�)(.

CO

RE

GLO

BA

L TE

CH

NO

LOG

IES,

LLC

Tot

al12

3,28

9.76

��

:/

��

8008

4078

6�

��

�>%�

��#

�$%�

��!

!��#�

"��:

��

�=�K

��

.�'&

*)��

DEM

AR

K IN

C T

otal

6,41

2.80

��

:��

��

��

H��

��

��

H��

�80

0845

380

��

��>

%��

�#�$

%�"��

��

��!

!��#

&��

�A)*

AD

OM

INIO

N E

NG

INEE

RIN

G IN

C T

otal

13,0

85.2

5�

D�

��

��

��

�)

8008

4268

6�

��

�>%�

��%

>#��

H

��

?��

��

��

�*A�

)'�

EXPO

NEN

T, IN

C. T

otal

98,2

53.4

3H

�/

��

� �

/

��/

��

��G

��

<

��

�80

0840

786

��

��>

%��

�#�$

%��

�!!�

�#�"��

:�

��=

�K��

�.&

�)*�

GC

A N

UC

LEA

R F

AC

ILIT

Y SE

RVI

CES

Tot

al61

3.20

��

��

��

8008

4080

7�

��

��

�!!�

�#�L�

��

��K>

N%��

@%��

��#�

$%.'

��

)��

8008

4268

6�

��

�>%�

��%

>#��

H

��

?��

��

��A

��A�

)��

8008

4340

3�

��

�>%�

��%

>#��

H

��

?��

��

*''�

'**)

*A80

0843

405

�*�

��%

>#��

H

��

?��

��

'**�

&�&)

��IN

TEC

H IN

C T

otal

767,

334.

08��

��

��

��

/��

��

8008

4340

3�

��

�>%�

��%

>#��

H

��

?��

��

&��

(.)(

�80

0843

405

�*�

��%

>#��

H

��

?��

��

&��

(.)(

�IN

TER

TEK

USA

, IN

C T

otal

20,1

53.5

6 /

:,

�

��:

/�

H�

��

�:

/�

��

8008

4083

1<

%��

��>�K

#�>�@

@%>#

��

��

H��

��>%

��

#$�*

&&��

��)�

�

�"'

��%

!��%

�R��

,��,

+��

Func

tiona

l Gro

upC

ost E

lem

ent G

roup

Ve

ndor

Ord

er N

umbe

rO

rder

Des

crip

tion

Tota

l

Con

trac

tors

and

Con

sulta

nts

Supp

ortin

g St

eam

Gen

erat

or In

spec

tion

and

Rep

air A

ctiv

ities

(201

2 $,

100

% L

evel

)

Engi

neer

ing

Con

trac

tLA

MB

ERT

MA

CG

ILL

THO

MA

S IN

C T

otal

11,8

88.0

0 �

H�

�,

��H

��

�

��

/

��

�80

0911

398

�*�

%#

��

#��

%�=�

>%��

#%�

�H%�

%��#

��

:�

&��

�()A

�LI

GH

TBR

IDG

E C

OR

POR

ATI

ON

Tot

al10

,837

.50

:��

��

��+

��

��

��

8008

8920

0:

/��

�/

��

� G

�L��/

�D

�,��

@%�

'.�A

��)�

�M

O D

ION

& S

ON

S IN

C T

otal

46,5

00.0

0:

/�

��

� �

��

��

H

G��

�

<��

��

��

�

�

/�

8009

2573

2,

�K%�

�N�

�$%�

��

�L��

��

%�>#

��

%L�%

@��

A'�(

.�).

�80

0937

520

��!

!��#�

�H

�%>

�=%�

M��

LL@��

��

��

%�>#

��

A�*�

�)'�

MA

STER

LEE

EN

ERG

Y SE

RVI

CES

CO

RPO

RA

T To

tal

450,

000.

00:

��

��

��/

<��

H�/

��

��

/ �

�H

��

8008

8435

6�

�!��

��%�

"��

>?��

$�>�

K#K�

L��/

�W�,

@��

�.�)

��M

ISSI

ON

PA

VIN

G A

ND

SEA

LIN

G IN

C T

otal

3,36

0.00

:��

��

,��

��

��

�/

��

��

H

G��

G�

��:

��

8008

4255

4VV

��

��>

%��

�#�$

%�*�

&*�"�

��:

&.A�

&*�)

��80

0873

488

��

#�*��

H�

%#��

��#�

��%�

=�>%

��

�&)�

�M

ITSU

BIS

HI N

UC

LEA

R E

NER

GY

SYST

EMS,

Tot

al19

5,45

1.00

:�

�/

��

��

�/��

��

�80

0843

403

��

��>

%��

��%>#

��H

��

��?�

��

�A�

��(�

&)&&

8008

4340

5�

*��

��%>#

��H

��

��?�

��

��*

(�**

�)A'

MPR

ASS

OC

IATE

S IN

C T

otal

1,52

6,95

1.65

�/

��

�/

��

��

��

��

��+

��

��

� �

/�

��

8008

4080

7�

��

��

�!!�

�#�L�

��

��K>

N%��

@%��

��#�

$%&�

�.&�

)&&

NA

TIO

NA

L IN

SPEC

TIO

N &

CO

NSU

LTA

NTS

, Tot

al10

,618

.11

�/

��

��

��

�,�

� �

��

��

)80

0884

356

��!

��

%�"�

��>?

��$�

>�K#

K�L�

��/�W

�,@�

(&��

'.�)

*'N

ATI

ON

WID

E B

OIL

ER, I

NC

. Tot

al71

0,46

9.24

��

��

�

��

�<

��

�:

��

�/ �

��

)80

0884

356

��!

��

%�"�

��>?

��$�

>�K#

K�L�

��/�W

�,@�

(A)A

�80

0911

398

�*�

%#

��

#��

%�=�

>%��

#%�

�H%�

%��#

��

:�

A�.)

'�N

EW W

OR

LD E

NVI

RO

NM

ENTA

L, IN

C. T

otal

582.

06�

��

�:

��

��

�

F��

�80

0840

831

<%�

��>

�K#�>

�@@%

>#��

��

�H

��

>%��

�#$

�*&*

�'�(

)�(

OLD

DO

MIN

ION

PR

OJE

CT

Tota

l12

,497

.97

F�

/�

��

�

��

�+�/

��

��

�/��

��

�80

0842

686

��

��>

%��

��%>#

��H

��

��?�

��

��

&��&

&�)�

�R

J A

ND

ERSO

N &

ASS

OC

IATE

S, L

LC T

otal

10,1

13.0

0�

��

��

��

"/�,

��

��

��

��

��

��

�

��

8008

4078

6�

��

�>%�

��#

�$%�

��!

!��#�

"��:

��

�=�K

��

&.��

.�)&

�SC

IEN

TEC

H-A

BU

SIN

ESS

UN

IT O

F C

UR

TIS

Tota

l16

,860

.18

�:

/

��

�H�

/

8008

4340

6�

*��

��%>#

��H

��

��?�

��

��

�&�*

A�)�

�SM

AR

T SI

GN

AL

Tota

l31

,250

.00

��

��

�+��

�,

��

��

��

��

��

��

��

��

8005

8992

2*�

��

��

M��

��%

�#��

%K#��

$��

��

P%��

@�$

'��A

*)�*

8006

9488

0�

��M�

��

�%�#

��%K

#��$�

��P%

��!#

�>��

�P@%

��**

�'�*

)A(

8006

9488

1�

%��'

�L��

EH��

��?)

�%

�=%�

+�

%!@�

>%��

%�*�

*�')

(�80

0840

786

��

��>

%��

�#�$

%��

�!!�

�#�"��

:�

��=

�K��

�&�

&��

.(&)

&(80

0841

185

�>�

LL�@�

��&

��&:

��

��

��N

�@%K

A.��

.�).

*80

0841

957

��

#��

�P%�

��!#

�>�>

�P@%

��K#

�@@�

#��

��*

()&�

8008

4199

2�

�R��

��

��

*��%

K#�

��L�

@�I�

%P�*

�&*�

��>

*�A�

�)(�

8008

4257

5�

��

��

��

�

��

��

��

��

�E�

��

��

��

��

X�

��(�

��'.

)'�

8008

4257

7�

>�LL�

@��

��

%�)��

'��

�#K�

�%��

��#�

��

%�#

A�.'

.).'

8008

4257

8�

��

%��'

�L��

EH��

��?)

�%

�=%�

+�

%!@�

>%&&

�&'�

)(�

8008

4267

4�

��#%

!�

��M

�!��

%��L�

�>%�

��#

�$%

��'

��)*

�80

0842

721

��

�>�

LL�@�

��%�

)��'�

��K�

�%��

��#�

��

%�#

&��

A()*

A80

0842

846

��

R��

��

�*�

��%

KK��

%��%

K#�K

�!!�

�#�I�

%P&�

��

)��

8008

4341

8�

>�LL�

@��

�&��

&:�

��

��

�N�@

%K.&

�*��

)'*

8008

4623

0*�

��

K%>�

��

M�K�

�%�L�

@@�L��

�N

�K%

**�(

�A)�

�80

0846

427

�%�

L��

��

��

�!!%

��#�P

%�>�

%�

��

K!%>

#�*&

��.�

)A�

8008

4987

0O�

��

�

��

��

�/H

�O��

��=�

�%�K

�!!�

�#�#�

��!

'�*�

')(.

8008

5001

0*�

��

��

%��

��K!

%>#��

!!%�

�#�P%

�P��

�@%

*��

�().

.80

0850

012

��

��

��>�

%�

��

K!%>

#��!!

%��#�

P%�P

��@

%&A

�*&�

)((

8008

5075

0��

�&.

,��

!K��

M��

��%

!��

!#'�

��)

A�80

0850

772

��

R��

��

�O�!!

%�"�

%K#O�

��

�N�@

%�>�

%�

�.�

'(*)

&*80

0850

773

��

R��

��

O�!!

%�"�

�K#O�

��

�N�@

%�>�

%�

�&*

��('

)&'

�"A

��%

!��%

�R��

,��,

+��

Func

tiona

l Gro

upC

ost E

lem

ent G

roup

Ve

ndor

Ord

er N

umbe

rO

rder

Des

crip

tion

Tota

l

Con

trac

tors

and

Con

sulta

nts

Supp

ortin

g St

eam

Gen

erat

or In

spec

tion

and

Rep

air A

ctiv

ities

(201

2 $,

100

% L

evel

)

Engi

neer

ing

Con

trac

t�

��

��+

��

,�

��

��

��

��

��

��

��

�80

0850

895

*��

��*�

��

� %�

��

K!%>

#��

�L�K

%>��

��M

�'��

A�)'

A80

0851

614

�*�

��

��O�

!!%�

"��K

#O�I*

(��

%$�%

%J��

��

N*�

�*.)

A&80

0854

459

��

��

��

#%�

�H%�

%��#

��K�

#��

��

�&(

��.&

)��

8008

5448

4�

*��

%��

'�K�

!!��

#�"�K

N�!�

!�%L

�P'�

'AA)

&.80

0854

485

�*R

��K#

�@@�L

@��$

%E>�

P@%�

L�W#�

�%��

#�!%�

.��

A)&*

8008

5452

6�

��

��"�

/

��EH

��

��

>#�=

�#�%K

*��&

')�'

8008

6051

5�

��R��

��

��O�

!!%�

"�%K

#O��

��N

�@%�

>�

%��

'�AA

&)&(

8008

6721

6�

�!!�

�#��

�%��#

��

��

�E�

��

��

��#�*

��U�

�!��

�*(�

)*(

8008

7239

6

%!��

��*�

�%�

��'�

#%

!�L@�

�$%E

>�P@

%�K%

�@*�

(.�)

&�80

0884

356

��!

��

%�"�

��>?

��$�

>�K#

K�L�

��/�W

�,@�

�..�

'�&)

(.80

0888

101

�>�

LL�@�

�K�!

!��#�

L��#

N%��

K#�@

@�#��

��L

�'�A

&().

&80

0888

564

/�W

,��

@%�"

��K�

�@@��

��

!@�#

%KE!

��?�

#��@

'A�(

(�)A

.80

0888

820

��P�

�>�#

%��

��

K#�@

@�#N%

��%U�

��%��

�%>

��&

�.'.

)��

8008

9060

6*�

��

��

%��

��K!

%>#��

!!%�

�#�P%

�P��

�@%

��.

A)��

8008

9322

9��

K#�@

@Y�!�

!��$

� ��

�L�@�

K��N

�K%K

��

�>�

'A�(

*�).

'80

0895

164

/�W

�,��

@%��

% !�

��!

!��#)

��

/�

��,

�*(�

*�*&

��&

)�(

8008

9710

8/

�W�,

��@%

�E��%

"L�P�

+��

#�$%

��P

@%K�

��

/'�

�***

)�A

8009

0190

3�

�%"�

�P�,

��@%

��

��

%��%

�K*'

�A�&

)''

8009

0713

6�

%��

'�L@�

�$%E

>�P@

%�#%

!�

L�W#�

�%(�

��&)

.A80

0907

137

�%

!��

��%�

��*�

�#%

� �H

%�%�

�#��

��P

%��

W!��

&��

*'�)

A'80

0907

819

�*�

�!%

�E�

@�K%

��U�

�!��

�#>N

&*(�

'�()

��80

0909

676

:��

�LM��

%>��

�#M��

��>%

�@

%�#��

@�#%

K��#

��A

��

�)�'

8009

1139

8�

*�

%#��

��#�

��%�

=�>%

��#%

� �H

%�%�

�#��

��:

��&

'�A(

�)��

8009

1144

0�

��

%#��

��#�

��%�

=�>%

��#%

� �H

%�%�

�#��

��:

�*A

&�'&

�)(�

8009

1150

4�

*��

��#�

%"��

��K#

�@@E

% �=

%��

H��

��

��

&��'

&.)*

*80

0911

510

*��

��

��

��

!@�$

KEK#

�P�@�

T%�K

*��'

��)(

�80

0911

645

�*�

�H

��N�

K%�*

��

�K>�

LL�@�

�K�!

!��#

&��*

�)''

8009

1164

6�

*��

H��

N�K%

�*��

��M�

>��

%�#�K

>�LL�

@�K

��&

*�)&

*80

0911

648

�*�

�H

��N�

K%�*

�,+

��K

>�LL�

@�K�

K�!!

��#

*�.�

�)&*

8009

1175

9�

*��

H��

N�K%

�*�,

+�

��K�

@�#�

��K�!

!��#

'�A�

�)�.

8009

1178

6�

>�LL�

@��

��

��

M��

��%

�#��

��

H��

N�K%

�*&�

�***

)(.

8009

1198

9*�

��

��

��

��!@

�$KE

K#�P

�@�T%

�K(*

��.�

)(.

8009

1275

5:

��LM

�%W�

K#��

$��

%>��

�#M��

��>%

�@

%�#�,

��**

��

)('

8009

1434

7�%

!�

��

%��

��

#%�

�H%�

%��#

��

K!%>

#��

''�A

��)�

(80

0915

050

��

�%�

��'�

#%

!�K%

�=�>

%�N%

��

A(�)

**80

0922

891

�D�

�*�R�

��

��

P%KN

%%#�K

#��$

N#�%

KKA�

��()

A�80

0926

727

��K#

�@@�>

�=%�

K��

��*�

W�

��=

�#M��

@$��

��K

*A�)

&�80

0927

138

%L

%�%�

>%��

��*

�*�(

(A&�

"�R�

% �=

%� �

��%�

.��*

�)��

8009

2742

6��

K#�@

@�>�=

%�K�

��

��

W��

�=�#M

��@$

��

K)�'

�)��

8009

3059

2�

%�K�

��K

#�@@�

#��

�*�

��

#��

%�

#��<

�:

&'.�

'�&)

.�80

0930

593

�*�

��

#��

%�

#��<

�:

��

!$��

�%�/

��

�*��

�A��

)'�

8009

3331

9*�

��

�!@

�#��

#�P�

@�T%�

R�/�

��

��.'

'*��

��

*��A

�')&

'80

0937

301

�*�

��

!E��

K�@�

#��<

�:

��

!$��

�%�/

��

*).�

�(�&

)'&

8009

3752

0�

�!!�

�#��

H�

%>�=

%�M�

��LL@

��

��

%�

>#��

*'�A

�&)�

*80

0952

923

*D�

�*�R�

*��

��

%>�K

��%�

��

H�#%

K#�"�

%K#��

��'�

�).(

8009

5292

4*D

��*

�R�*�

��

�%>

�K��

%��

��H

�#%K#

�"�%K

#��(�

'��)

(�80

0981

367

< �

:�

��!$

��%

��+

:��%

@�#%

��>�

K#�#�

�>�!

�#�A*

��

�)��

STO

NE

& W

EBST

ER C

ON

STR

UC

TIO

N, I

NC

Tot

al4,

916,

551.

29��

��

��

�,

��H

��

�:

�/

��

��

�80

0840

786

��

��>

%��

�#�$

%��

�!!�

�#�"��

:�

��=

�K��

�(�

AAA)

�ATH

E FO

OTB

RID

GE

CO

MPA

NIE

S LL

C T

otal

7,55

5.05

��

GS�

� �

�

�:

��

�/�

��

/��

��

�

<��

�80

0840

786

��

��>

%��

�#�$

%��

�!!�

�#�"��

:�

��=

�K��

�*.

()(&

TON

Y'S

LOC

KSM

ITH

AN

D S

AFE

R S

ERVI

CE

Tota

l26

7.71

<��

��K

8008

4078

6�

��

�>%�

��#

�$%�

��!

!��#�

"��:

��

�=�K

��

'��'

&)A*

�".

��%

!��%

�R��

,��,

+��

Func

tiona

l Gro

upC

ost E

lem

ent G

roup

Ve

ndor

Ord

er N

umbe

rO

rder

Des

crip

tion

Tota

l

Con

trac

tors

and

Con

sulta

nts

Supp

ortin

g St

eam

Gen

erat

or In

spec

tion

and

Rep

air A

ctiv

ities

(201

2 $,

100

% L

evel

)

Engi

neer

ing

Con

trac

t<

��

�K80

0845

641

�+

��

�!!�

�#��

��?�

L��

��

�>%�

��#

�$%

*(()

**80

0884

356

��!

��

%�"�

��>?

��$�

>�K#

K�L�

��/�W

�,@�

&.�*

(�)�

�80

0922

891

�D�

�*�R�

��

��

P%KN

%%#�K

#��$

N#�%

KK((

)��

Vario

us T

otal

21,4

67.4

4<

��

�KR�,

��#@%

##��

�>@%

��

��

#��%

�+��

%PK#

%�80

0589

922

*��

��

��M�

��

�%�#

��%K

#��$�

��

��P%

��@�

$I�

��

)&.J

8005

8992

8*�

��

��

M��

��%

�#��

%K#��

$��

��

P%��

@�$

IA��

&')A

.J80

0694

881

�%�

�'�L�

��EH

��

?)�

% �=

%�+

�%!

@�>%

��%�

I*��

A&)(

�JVa

rious

: Bar

tlett

Nuc

lear

and

Sto

ne &

Web

ster

Tot

al(1

0,46

4.50

)<

��

�KR�,

��#@%

##��

�>@%

��

#��%

�+��

%PK#

%��

N��>

%��

��?L

��>%

8005

8992

2*�

��

��

M��

��%

�#��

%K#��

$��

��

P%��

@�$

I��

'��)

A�J

8006

9488

0�

��M�

��

�%�#

��%K

#��$�

��P%

��!#

�>��

�P@%

��I&

&�&A

�)�*

JVa

rious

: Bar

tlett

Nuc

lear

, Sto

ne &

Web

ster

, Cho

ice

Wor

kfor

ce T

ota l

(91,

590.

40)

��

��

�H

��

��

��

��

��

��

� �

8008

5942

1VV

��

��%

>#��

H

��

?��

�:.�

�(��

)��

WES

TIN

GH

OU

SE E

LEC

TRIC

CO

LLC

Tot

al63

,700

.00

��

��

�H

��

��

��

��

��

��

:�

/�

G�

�80

0840

807

��

��

��!

!��#�

L��

��

K>N%

��@%

��

#�$%

&(��

*�)�

�80

0842

554

VV��

��

�>%�

��#

�$%�

*�&*

�"��

�:&*

��*

A)��

8008

4340

3�

��

�>%�

��%

>#��

H

��

?��

��

��

�(A)

.�80

0843

405

�*�

��%

>#��

H

��

?��

��

��&*

.�*'

.)��

8008

5706

2VV

��*�

��%

>#��

H

��

?��

�:**

.��

�)��

8008

7348

8�

��#�*

��H

�%#

��

#��

%�=�

>%*A

'�''

�)��

8009

3752

0�

�!!�

�#��

H�

%>�=

%�M�

��LL@

��

��

%�

>#��

*A��

'�)(

&W

ESTI

NG

HO

USE

ELE

CTR

IC C

OM

PAN

Y LL

C T

otal

4,76

1,36

4.24

Engi

neer

ing

Tota

l94

,646

,018

.63

Rad

Che

mC

ontr

act

,/

�

��

��

� �

/

��

8008

4080

9�

��

�>%�

��#

�$%�

��

H��

��"�

%�@#N

��NM

K�>K

&�*&

&��

A).�

8008

4726

6�

��

�>%�

��#

�$%�

��

H��

��"�

%�@#N

��NM

K�>K

��(�

��)

�(80

0847

272

�*�

�

%�$%

�#��

��?�

�*�

H��

��"�

%�@#N

��NM

K�>K

��'�

(�A)

��80

0847

273

�*�

�

%�$%

�#��

��?�

�*�

H��

��"�

%�@#N

��NM

K�>K

�.A�

.(.)

((B

AR

TLET

T N

UC

LEA

R IN

C T

otal

3,29

0,44

6.65

��

�

HG

��

��

��

��

�80

0840

809

��

��>

%��

�#�$

%��

��H

��

"�%�

@#N��

NMK�

>K(�

��

).�

8008

4726

6�

��

�>%�

��#

�$%�

��

H��

��"�

%�@#N

��NM

K�>K

A��

�')�

�80

0847

272

�*�

�

%�$%

�#��

��?�

�*�

H��

��"�

%�@#N

��NM

K�>K

*'��

(&)A

'80

0847

273

�*�

�

%�$%

�#��

��?�

�*�

H��

��"�

%�@#N

��NM

K�>K

A�'(

')�'

ENER

GY

SOLU

TIO

NS,

LLC

Tot

al16

9,71

1.26

��

��

��

:��

��

�/

�H

�

��

��

�)

8008

4080

9�

��

�>%�

��#

�$%�

��

H��

��"�

%�@#N

��NM

K�>K

*�.�

�)��

8008

4727

2�

*��

%�

$%�#

��

?��

*�H

��

"�%�

@#N��

NMK�

>K''

�.��

)((

8008

4727

3�

*��

%�

$%�#

��

?��

*�H

��

"�%�

@#N��

NMK�

>K''

��

).�

SPEC

TRU

M N

UC

LEA

R G

RO

UP,

INC

. Tot

al91

,542

.46

��

��

��

��

<

��

��H

�

��

��

8008

4080

9�

��

�>%�

��#

�$%�

��

H��

��"�

%�@#N

��NM

K�>K

��(�

�&�)

(.80

0847

266

��

��>

%��

�#�$

%��

��H

��

"�%�

@#N��

NMK�

>K��

��*.

*)&(

8008

4727

2�

*��

%�

$%�#

��

?��

*�H

��

"�%�

@#N��

NMK�

>K�*

&�*.

�).&

8008

4727

3�

*��

%�

$%�#

��

?��

*�H

��

"�%�

@#N��

NMK�

>K�*

A�.�

A)�.

UN

ITEC

H S

ERVI

CES

GR

OU

P IN

C T

otal

1,44

3,17

5.50

Rad

Che

m T

otal

4,99

4,87

5.87

Reg

ulat

ory

Con

trac

t�

�

��

��

�

��

/

��

�80

0922

248

�*�

H��

%�

$%�#

��

?�"��

/

��!

!��#

&*�.

�A)A

AC

ERTR

EC C

OR

POR

ATI

ON

Tot

al12

,695

.55

�H

��,

��

H�

��

�

�

/��

��

8009

2224

8�

*�H

��

%�$%

�#��

��?�

"��

/��

�!!�

�#*�

��'

)&�

LIG

HTB

RID

GE

CO

RPO

RA

TIO

N T

otal

28,3

84.1

0

M��

�)��

%��

�M80

0922

248

�*�

H��

%�

$%�#

��

?�"��

/

��!

!��#

*A)�

�R

yan

I. Tr

eadw

ay T

otal

25.0

0��

��

��

:��

��

�/

��

�/

��

�

��

/

��

�80

0841

770

��

��>

%��

�#�$

%�"��

/

��!

!��#�

*�&*

&�&.

�)��

TEC

HC

OM

INTE

RN

ATI

ON

AL

CO

RPO

RA

TIO

N T

otal

1,16

0.00

��

�/�

��

��/

��

8009

2224

8�

*�H

��

%�$%

�#��

��?�

"��

/��

�!!�

�#*�

��.

)'�

WD

ASS

OC

IATE

S To

tal

28,8

86.4

8R

egul

ator

y To

tal

71,1

51.1

3

�"(

��%

!��%

�R��

,��,

+��

Func

tiona

l Gro

upC

ost E

lem

ent G

roup

Ve

ndor

Ord

er N

umbe

rO

rder

Des

crip

tion

Tota

l

Con

trac

tors

and

Con

sulta

nts

Supp

ortin

g St

eam

Gen

erat

or In

spec

tion

and

Rep

air A

ctiv

ities

(201

2 $,

100

% L

evel

)

Secu

rity

Con

trac

t/

�

��

�D

��

�H

G��

�

<��

��

8008

4129

6/

>>%K

K�/

�#N�

��T�#

��

��

��>

%��

�#�$

%*.

.)��

ALE

RE

TOXI

CO

LOG

Y SE

RVI

CES

Tot

al26

6.00

��

��

��

�

��

�

��

� �

��

��

��

8008

4129

6/

>>%K

K�/

�#N�

��T�#

��

��

��>

%��

�#�$

%��

'��)

&�80

0868

171

�%>

��#M

��*�

�H

��

%�

$%�#

��

?'�

.�')

'.C

HO

ICE

WO

RK

FOR

CE

SOLU

TIO

NS,

LLC

Tot

al8,

042.

59�

��

/�

��

<�

��

H/

��

��

��

�

8008

4129

6/

>>%K

K�/

�#N�

��T�#

��

��

��>

%��

�#�$

%'�

�*')

'API

NN

AC

LE IN

VEST

IGA

TIO

NS

CO

RP

Tota

l4,

824.

45Se

curit

y To

tal

13,1

33.0

4N

ucle

ar S

uppo

rtC

ontr

act

/�

��

�:

:�

��

/��

��

��

�80

0845

391

��

��>

%��

�#�$

%��

��

!�+

��%@

%>�

��

�

&.')

��80

0921

685

��N�

K%��

�*�

�#%

� �H

%�%�

�#��

�%!

��

*�A.

*)A�

8009

2387

0��

H

��

&�"�

%@�>

�#%�

�H

��

%�K�

��%@

�&&

�&��

)�&

AC

S C

OM

MU

NIC

ATI

ON

S IN

C T

otal

13,9

16.4

1/

�:

��

�/

��<

��

��

��

�80

0901

688

��

��>

%��

�#�$

%�"�,

�K��

%KK�

K�!!

��#)�

��N

*.��

(�)�

�80

0901

943

�*�

�H

�"�

,�

��

��

��

��

��

�)

��N�

�$%�

#N�K

*��

��)�

�A

DM

INIS

TRA

TIVE

CO

NTR

OLS

Tot

al55

,800

.00

/

�<

/��

�80

0921

685

��N�

K%��

�*�

�#%

� �H

%�%�

�#��

�%!

��

'��

&.()

��A

REV

A N

P To

tal

400,

167.

00,

/

� �

��

��

�/

��

��

8009

5976

8��

H

Q�*�

�%�

L��

� �K

%��

>��

�L��

*��

��#�

��

�&�

�.�)

��B

AR

TLET

T N

UC

LEA

R IN

C T

otal

1,36

0.80

, /

�

��/

:�

��

��

<

��

��

�80

0842

079

��

��

��

�>%�

��#

�$%�

��

��

��K

#K�K

!@�#

'��*

'�)(

A80

0921

685

��N�

K%��

�*�

�#%

� �H

%�%�

�#��

�%!

��

&�A(

*��

�)�&

8009

2168

6��

N�K%

��

��

#%�

�H%�

%��#

��

%!��

��'�

.(&)

.(80

0928

623

��H

Q�

%�

��$

"��#�

�#��

��&�

A�(*

�)��

8009

2862

4��

H

Q�%�

��

�$"�

@��

��$�

+��

�%!�

&��

(�)�

�80

0928

629

��H

Q�

%�

��$

"��

=%@�

'�&A

.)'�

8009

2863

3��

H

Q�%�

��

��>�

�%

%�#"�

@��

��$�

+��

�%!�

A�&'

')�.

8009

2863

8��

H

Q�%�

��

��>�

�%

%�#"�

��=%

@�&'

�).�

8009

2880

1��

H

Q�%�

��

��K#

��>#

��"

��#�

�#��

��&�

��'A

)��

8009

2880

3��

H

Q�%�

��

��K#

��>#

��"

�@�

��

$�+

��%

!�(�

��&)

��80

0928

804

��H

Q�

%�

��

K#��

>#��

�"��

��

�$�+

��$

��T

�&�

�&')

��80

0942

977

��*+

��

%#��

��

��%�

=�>%

�"��=

�K��

��

�!!�

�#�A&

��&(

.)��

BLA

CK

DIA

MO

ND

SER

VIC

ES IN

C T

otal

2,28

7,90

3.51

��

��

��

�

��

�

��

� �

��

��

��

8008

4207

9�

��

��

��>

%��

�#�$

%��

�

��

�K#K

�K!@

�#&'

��&

()*&

8009

0168

8�

��

�>%�

��#

�$%�

"�,�K

��%K

K�K�

!!��

#)��

N&*

�)'*

8009

0194

3�

*��

H

�"�,

��

��

��

��

��

�

�)��

N��$

%�#N

�K&*

�)'*

8009

2168

5��

N�K%

��

*��

#%�

�H%�

%��#

��

%!��

��&&

'��

�)��

8009

2168

6��

N�K%

��

��

#%�

�H%�

%��#

��

%!��

��'�

'(�)

��80

0923

870

��H

��

�&�

"�%@

�>�#

%��

H

��%�

K��

%@�

.��

')�&

8009

2863

1��

H

Q�%�

��

��>�

�%

%�#"�

��#��

#��

(�A�

*)&'

8009

2863

3��

H

Q�%�

��

��>�

�%

%�#"�

@��

��$�

+��

�%!�

*��'

�)'�

8009

2863

4��

H

Q�%�

��

��>�

�%

%�#"�

��

��$�

+��

�$��

�T��

&�(�

�)A�

8009

2880

3��

H

Q�%�

��

��K#

��>#

��"

�@�

��

$�+

��%

!�&�

�.��

)��

8009

4297

7��

*+��

%#

��

��

%�=�

>%�"�

�=�K

��

��!

!��#�

&(��

��A)

�A80

0959

768

��H

Q�

*��

%�L�

� �

�K%�

��>�

��

L��*�

��

#��

�

'�&'

*)��

8009

5976

9��

H

Q��

�%�

L��

� �K

%��

>��

�L��

��

��#�

��

�A�

�(�)

��C

HO

ICE

WO

RK

FOR

CE

SOLU

TIO

NS,

LLC

Tot

al48

9,07

7.32

��

� �

��

��

��

<

��

�80

0942

977

��*+

��

%#��

��

��%�

=�>%

�"��=

�K��

��

�!!�

�#��'

��

)��

CIR

CLE

WO

OD

SER

VIC

ES T

otal

84,9

80.0

0�

��

��

��

:��

G�

/:

��

��

��

8009

4297

7��

*+��

%#

��

��

%�=�

>%�"�

�=�K

��

��!

!��#�

&.�*

'A)&

'C

ON

TIN

UU

M D

YNA

MIC

S, IN

C T

otal

16,2

45.1

4�

��

�80

0842

079

��

��

��

�>%�

��#

�$%�

��

��

��K

#K�K

!@�#

&*�.

*�)'

AEE

CS

Tota

l12

,623

.45

�:

"F/

G��

��

8009

4709

4��

*"

��:

�K>�

�W!

%�K%

K��

�

�A*'

��H

�%#

��

'&')

��

�"�

��%

!��%

�R��

,��,

+��

Func

tiona

l Gro

upC

ost E

lem

ent G

roup

Ve

ndor

Ord

er N

umbe

rO

rder

Des

crip

tion

Tota

l

Con

trac

tors

and

Con

sulta

nts

Supp

ortin

g St

eam

Gen

erat

or In

spec

tion

and

Rep

air A

ctiv

ities

(201

2 $,

100

% L

evel

)

Nuc

lear

Sup

port

Con

trac

tEM

-JA

Y IN

C T

otal

414.

00�

:�

��

��

/�

��

�

�/��

��

��

�)�

8009

2168

5��

N�K%

��

*��

#%�

�H%�

%��#

��

%!��

��.�

*�&)

*AEM

PIR

E TR

AN

SPO

RTA

TIO

N, I

NC

. To

tal

6,28

1.25

H/

G

��/

�G

8008

8229

9�

��

H��

%�

$%�#

��

?��"�

��

��

�!!�

�#��

�)��

GA

RY

PAR

KEY

Tot

al80

0.00

H/

G

��

��

��

�80

0882

298

��

#�*��

%�

$%�#

��

?��

*�H

�"��

��

��!

!��#

&��

�)��

GA

RY

PETE

RSO

N T

otal

1,00

0.00

H�

/��

��

�/

��

/�

� ��

G��

�

<��

��

�80

0921

685

��N�

K%��

�*�

�#%

� �H

%�%�

�#��

�%!

��

&&')

��80

0923

870

��H

��

�&�

"�%@

�>�#

%��

H

��%�

K��

%@�

A��)

&*80

0928

634

��H

Q�

%�

��

>��%

%�

#"��

��

$�+

��$

��T

��**

�)�A

GC

A N

UC

LEA

R F

AC

ILIT

Y SE

RVI

CES

Tot

al87

8.05

��

� �

��"�

/�

/

�

��

:�

/�

G80

0845

391

��

��>

%��

�#�$

%��

��

!�+

��%@

%>�

��

�

��.�

�)��

HEW

LETT

-PA

CK

AR

D C

OM

PAN

Y To

tal

8,69

9.00

��

��

80

0921

685

��N�

K%��

�*�

�#%

� �H

%�%�

�#��

�%!

��

A��

�A)�

�IN

TER

TEK

Tot

al58

,395

.00

�H

��,

��

H�

��

�

�

/��

��

�80

0942

977

��*+

��

%#��

��

��%�

=�>%

�"��=

�K��

��

�!!�

�#�&A

��

)��

LIG

HTB

RID

GE

CO

RPO

RA

TIO

N T

otal

15,3

00.0

0:

�

�/�

��

��/

��

��

�80

0942

977

��*+

��

%#��

��

��%�

=�>%

�"��=

�K��

��

�!!�

�#�*(

*��.

�)��

MPR

ASS

OC

IATE

S IN

C T

otal

272,

360.

80�

��

��

�

��

<�

��

:�

��/

��

�)

8008

4207

9�

��

��

��>

%��

�#�$

%��

�

��

�K#K

�K!@

�#*�

'&')

A(N

EW W

OR

LD E

NVI

RO

NM

ENTA

L, IN

C. T

otal

2,41

4.57

��

��

:

/�

��

��

��

��

�

<��

��

��)�

)�80

0921

686

��N�

K%��

��

�#%

� �H

%�%�

�#��

�%!

��

*��

(&)(

*PE

RFO

RM

AN

CE

POW

ER S

ERVI

CES

, P.C

. To

tal

28,0

71.7

2

�,

�

��

�, �

<��

��

8009

4709

4��

*"

��:

�K>�

�W!

%�K%

K��

�

�A*'

��H

�%#

��

��

.)*'

RO

BER

T D

BLE

VIN

S T

otal

3,39

6.24

��

��

��

:��

��

�/

�H

�

��

��

�)�

8009

5976

9��

H

Q��

�%�

L��

� �K

%��

>��

�L��

��

��#�

��

�*�

.A�)

*�SP

ECTR

UM

NU

CLE

AR

GR

OU

P, IN

C.

Tota

l2,

659.

20�

��

��/

�

8009

2862

8��

H

Q�%�

��

�$"�

%�=�

>%K�

&��

�)��

SPIN

ITA

R T

otal

1,08

0.00

��

��

�+��

�,

��

��

��

��

��

��

��

��

8008

4207

9�

��

��

��>

%��

�#�$

%��

�

��

�K#K

�K!@

�#&A

�*�'

)'*

8008

4756

2�

��

��*�

�H

��

%�$%

�#��

K!%>

#��K

�+�

%!��

�K��

*��)

��80

0921

685

��N�

K%��

�*�

�#%

� �H

%�%�

�#��

�%!

��

�'�'

*.)(

'80

0923

870

��H

��

�&�

"�%@

�>�#

%��

H

��%�

K��

%@�

*.'�

&��)

�.80

0928

803

��H

Q�

%�

��

K#��

>#��

�"�

@��

��$�

+��

�%!�

��

'&)(

�80

0942

977

��*+

��

%#��

��

��%�

=�>%

�"��=

�K��

��

�!!�

�#�*.

�*'*

)&�

STO

NE

& W

EBST

ER C

ON

STR

UC

TIO

N, I

NC

Tot

al43

1,34

2.01

�G

��

:��

��

��

�80

0921

685

��N�

K%��

�*�

�#%

� �H

%�%�

�#��

�%!

��

&��

A.�)

��80

0928

635

��H

Q�

%�

��

>��%

%�

#":�#

%��

@K�

&��

�.)�

�SY

STEM

ON

E, L

LC T

otal

144,

399.

00�/

��

:/

��

��

�/

��

�/

��

�80

0845

381

��

��>

%��

�#�$

%�"��

��!

!��#

&**�

'*�)

*�80

0882

289

�*�

�

%�$%

�#��

��?�

�*�

H�"�

��!

!��#

&'.�

('')

&(TA

LISM

AN

INTE

RN

ATI

ON

AL,

LLC

Tot

al26

9,17

2.40

��

��

��,

��

H�

��

:�

/�

��

� �

�80

0921

685

��N�

K%��

�*�

�#%

� �H

%�%�

�#��

�%!

��

��

��)&

A80

0928

633

��H

Q�

%�

��

>��%

%�

#"�@�

��

$�+

��%

!�&�

��'

)�A

THE

FOO

TBR

IDG

E C

OM

PAN

IES

LLC

Tot

al99

,798

.10

��

GS�

� �

�

�:

��

�/�

��

/��

��

<

��

�80

0923

870

��H

��

�&�

"�%@

�>�#

%��

H

��%�

K��

%@�

.�'�

�)�(

TON

Y'S

LOC

KSM

ITH

AN

D S

AFE

SER

VIC

E T

otal

6,43

9.37

<��

��K

8009

2387

0��

H

��

&�"�

%@�>

�#%�

�H

��

%�K�

��%@

�&�

�A&�

)�A

8009

4297

7��

*+��

%#

��

��

%�=�

>%�"�

�=�K

��

��!

!��#�

&��

�)��

8009

4709

4��

*"

��:

�K>�

�W!

%�K%

K��

�

�A*'

��H

�%#

��

.'.)

.�V a

rious

Tot

al15

,244

.98

��

�/�

��

��/

��

8008

4538

1�

��

�>%�

��#

�$%�

"��

�!!�

�#�(

�(��

)��

WD

ASS

OC

IATE

S To

tal

37,7

00.0

0

�"�

��%

!��%

�R��

,��,

+��

Func

tiona

l Gro

upC

ost E

lem

ent G

roup

Ve

ndor

Ord

er N

umbe

rO

rder

Des

crip

tion

Tota

l

Con

trac

tors

and

Con

sulta

nts

Supp

ortin

g St

eam

Gen

erat

or In

spec

tion

and

Rep

air A

ctiv

ities

(201

2 $,

100

% L

evel

)

Nuc

lear

Sup

port

Con

trac

t�

��

��

H�

��

��

��

��

��

�:

�/

�G

� �

�80

0928

628

��H

Q�

%�

��$

"�%�

=�>%

K�*'

�A�(

)��

WES

TIN

GH

OU

SE E

LEC

TRIC

CO

MPA

NY

LLC

Tot

al24

,597

.00

Nuc

lear

Sup

port

Tot

al4,

792,

516.

31G

rand

Tot

al10

5,65

0,33

5.78

�"&

��

�%!�

�%�R

��,

��,+

��

Appendix E

ACRONYMS

E- 1

A ........................... 1 B ........................... 2 C ........................... 3 D ........................... 5 E ........................... 6 F ........................... 8 G ........................... 9

H ......................... 10 I .......................... 10 J .......................... 11 K ......................... 11 L ......................... 12 M ........................ 12 N ......................... 14

O ......................... 15 P ......................... 16 Q ......................... 18 R ......................... 18 S ......................... 20 T ......................... 22 U ......................... 23

V ......................... 24 W ........................ 24 X ......................... 25 Y ......................... 25 Z ......................... 25

1° leak rate – primary leak rate (Chemistry to Operations reporting of primary to secondary leak rates)

2° leak rate – secondary leak rate

AA – Alert (Declared Emergency) A ampere AACS – Automated Access Control System

(HP) (NIS) AAU – Access Authorization Unit (Support

Section) ABAM – Auxilliary Building Area Monitors ABR – Annual Biennial Review ABRD – Annual/Bi-Annual Review Date ac – alternating current AC – Acceptance Test Procedure AC – Alternating Current ACB – Air Circuit Breaker ACC – Arizona Corporation Commission ACE – SCE ASME Codes Engineer ACI – American Concrete Institute ACI – Auto-Closure Interlock ACIDS – Analytical Chemistry Information

Data System ACM – Accident Prevention Manual ACO – Assistant Control Room Operator ACORD – American Committee on

Radwaste Disposal ACP – Access Control Panel ACRS – Advisory Committee on Reactor

Safeguards ACS – American Chemical Society

ACSR – Aluminum Conductor Steel Reinforced

ACTS – Automated Control of Tools System

AD – Administrative Services (Identifier) AD&D – Accidental Death and

DismembermentADRS – Automated Document Retrieval

SystemADT – American Distance Telephone ADV – Atmospheric Dump Valve AE – Architect/Engineer AEC – Atomic Energy Commission AER – Authorized Edison Representative AF – audio frequency AFC – Application for Certification AFC – automatic frequency control AFW – Auxiliary Feedwater AFWAS – Auxiliary Feedwater Actuation

SignalAFWP – Auxiliary Feedwater Pump AFWS – Auxiliary Feed Water System AGC – automatic gain control Ah – ampere·hour AI – Authorized Inspector AIA – Authorized Inspection Agency AIF – Atomic Industrial Forum AIMS – Action Items Management System

(NIS)AISC – American Institute of Steel

ConstructionAISI – American Iron and Steel Institute AIT – Augmented Inspection Team AL – Administrative Leader (TSC) ALARA – As Low As Reasonably

Achievable

ACRONYMS

E- 2

AM – Amplitude modulation AM241 – Americium-241 AMP – Area Management Program AMU – Atomic Mass Unit AMS – Accident Monitoring System AMS – Automatic Mode Selector ANI – American Nuclear Insurance ANI – Authorized Nuclear Inspector ANII – Authorized Nuclear Inservice

InspectorANNUN – Annunciator ANPP – Arizona Nuclear Power Project ANS – American Nuclear Society ANSI – American National Standards

Institute, Inc. antilog – antilogarithm AOA – Acknowledgement of Acceptance

(Material Control) AOAC – Assistant Operational Area

Coordinator (NRC) AOI – Abnormal Operating Instruction AOO – Anticipated Operational

OccurrencesAOV – Air Operated Valve AP – Administrative Procedure (Projects) APC – Auxiliary Protective Cabinet APCB – Air Pollution Control Board APHA – American Public Health

AssociationAPI – Application Problem Interface APL – Approved Products List APM – Accident Prevention Manual APPA – American Public Power

AssociationAPS – Administrative Professional &

Supervisory APS – Arizona Public Service AQMD – Air Quality Management District AR – Action Request ARAC – Atmospheric Release Advisory

Capability (NRC) ARB – Air Resources Board ARC – American Red Cross (NRC) ARCA – Area Requiring Corrective Action

(NRC)

ARFI – Area Recommended for Improvement (NRC)

ARMS – Area Radiation Monitoring System ARO – All Rods Out ARP – Alarm/Annunciator Response

Procedure (also Alarm Response Instrctions)

ABB-CE – Asea Brown Boveri - Combustion Engineering

ASC – Affected Section Change ASI – Axial Shape Index ASL – Approved Supplier List ASLB – Atomic Safety Licensing Board ASME – American Association of

Mechanical Engineers ASNT – American Society for

Nondestructive Testing ASME – American Society of Mechanical

Engineers ASOS – Administrative Security Officer

Supervisor ASTM – American Society for Testing and

MaterialsAt – ampere·turn ATM – AtmosphereATSIS – Automated Technical Specification

Information System(NIS) ATWS – Anticipated Transient(s) Without

Scram (Events) ATWT – Anticipated Transient(s) Without

TripAUX – Auxiliary AVC – automatic volume control avg – average AWG – American Wire Gauge AWS – American Welding Society AWS Bldg. – Administrative Warehouse &

Supply/Shop Building

BBB's B&A – Budgets & Accounting BACKFIT – The word used to describe

forcing existing plants to meet new regulations

ACRONYMS

E- 3

BACT – Best Available Control Technology BAEAM – Boric Acid Evaporator Area

MonitorBAMT – Boric Acid Makeup Tank BAMU – Boric Acid Makeup bar – bar BARS – Boric Acid Recycle System BAS – Boric Acid System BAST – Boric Acid Storage Tank B&C – Boiler & Condensor B&CC – Budget and Cost Control Division

(SONGS)BCD – binary coded decimal BCT – Bushing Current Transformer B&FS – Business & Financial Services BeV – billion electronvolts (deprecated; use

gigaelectronvolt (GeV) BEIR – Biological Effects of Ionizing

RadiationBFO – beat·frequency oscillator BHP – Brake Horsepower BHP – Badge Holding Point BISI – Bypass & Inoperable Status

Indication Instrumentation BI – Background Investigation BID – Background Information on the

DeviceBLM – Bureau of Land Management BMS – Balanced Magnetic Switch BOC – Beginning of Cycle BOM or B/M – Bill(s) of Material BOP – Balance of Plant B/P – Bypass(ed) BPC – Bechtel Power Corp. BPO – Blanket Purchase Order BPPC – Boundary Point Power Correlation BPS – Blowdown Processing System B&PV – Boiler and Pressure Vessel (Code) BRC – Below Regulatory Concern BRPU – Biennial Resource Plan Update BQTR – Bechtel Quality Topical Report Btu – British thermal unit BW – Babcock and Wilcox (Nuclear Steam

Supply System) BWA – Backcharge Work Authorization BWO – backward·wave oscillator

BWPC – Bechtel Western Power Corporation

BWR – Boiling Water Reactor

Cc/s – cycles per second C – coulomb CA – Containment airborne CAA – Controlled Access Area CAD – Computer-Aided Dispatch System

(NRC)CADD – Computer Aided Design Drafting CAE – Condenser Air Ejector CAEG – Condensate Air Ejector Gas CAF – Corrective Action Follow-up cal – calorie CALTRANS – California Department of

Transportation (NRC) CAMS – Continuous Air Monitors CAR – Corrective Action Report CAR – Corrective Action Request CARB – California Air Resources Board CARS – Corporate Accounting Records

System (NIS) CAS – Central Alarm System CAS – Central Alarm Station CAS – Compressed Air System CASE – Coordinating Agency for Supplier

EvaluationCB – Circuit Breaker CBARS – Coolant & Boric Acid Recycle

SystemCBC – Critical Boron Concentration CBCS – COLSS Backup Computer System CBO – Control Bleed Off (ref RCP seals) CBOP – Continual Behavior Observation

Program(s)CBT – Computer Based Training CC – Carbon Copy and/or Courtesy Copy CC – Configuration Change/Control CC – Configuration Management (Identifier) CCAS – Containment Cooling Actuation

Signal

ACRONYMS

E- 4

CC&C – Configuration Control and Compliance

CCID – Central California Irrigation District CCIMS – Calculation Cross Index

Management System CCIP – Core Protection Calculator

Improvement Program CCPF – Controlled Computer Program File CCPI – Controlled Computer Program

IndexCCR – Configuration Control Report CCTV – Close-Circuit Television CCW – Component Cooling Water CCWS – Component Cooling Water

Systemcd – candela cd/ft2 – candela per square foot cd/m2 – candela per square meter CDM – Corporate Documentation

ManagementCDMC – Corporate Documentation

Management Center CDM&G – California Division Mines &

Geology CDMS – Corporate Documentation

Management System CDS – Corporate Documentation Services CDS – Corporate Documentation Systems CDU – Control Documents Unit

(Compliance Section) C-E (or CE) – Combustion Engineering CEA – Control Element Assembly CEAC – Control Element Assembly

Calculator CEACS – Control Element Assembly

Control System CEBUS – Control of Engineering Budgets

and Schedules CEC – California Energy Commission CED – Corporate Emergency Director

(EOF)CEDM – Control Element Drive Mechanism CEDMCS – Control Element Drive

Mechanism Control System CEND – Combustion Engineering Nuclear

Division

CEOG – C-E Owners Group CEP – Conceptual Engineering Package CESSAR – Combustion Engineering

Standard Safety Analysis Report CET – Core Exit Thermocouple CETB – Combustion Engineering Technical

Bulletin CF – Continuous Flow Respirator CFDM – Cognizant Functional Division

ManagerCFF – Construction Field Forces CFH – Certified Fuel Handler cfm – cubic feet per minute CFMS – Critical Functions Monitoring

System10 CFR – Code of Federal Regulations,

Part 10 (Energy) CFSM – Cognizant Functional Station

Managercgs – centimeter·gram·second CH – Chemistry (Identifier) CHF – Critical Heat Flux CHP – California Highway Patrol CHRS – Containment Heat Removal

SystemCi – Curie CIAS – Containment Isolation Actuation

SignalCIDR – Construction Inspection Data

ReportCIRCUS – Computer Information Radiation

Control Unusual/Universal Summary CIS – Bureau of Collection and

Investigation Services, California Department of Consumer Affairs

CIS – Containment Isolation System CISS – Contractor Information Sub-System

(NIS)CLAIR – COPE List Action Items Report CLRK – Control Room Log and Records

Keeper (NIS) CLSI – Cold Leg Safety Injection cm – centimeter cm3 – cubic centimeter CM – Condition Monitoring cmil – circular mil

ACRONYMS

E- 5

CMP – Configuration Management Program

CMTR – Certified Material Test Report CNG – California National Guard (NRC) CNT – Containment CNO – Chief Nuclear Officer CO – Control Operator (Operations

Division) COD – Commercial Operating Date COLSS – Core Operating Limit Supervisory

SystemCOM – Coal-Oil Mixture CONAC – Continuous Nuclear Analysis of

CoalCOPE – Control of Problem Equipment CP – Chemistry Program CP – Construction Permit CP – Control of Problem Equipment CPC – Core Protection Calculators CPD – Condensate Polishing Demineralizer CPF – Central Processing Facility CPIS – Containment Purge Isolation Signal CPPVS – Containment Purge Plant Vent

StackCPS – Cycles per Second CPT – Control Power Transformer CPUC – California Public Utilities

CommissionCR – Control Room (Plant Operations) CRACS – Chemical & Radiological Analysis

Computer System CRC – Centurion Research Corporation

(BI's) OR Corporate Records Center CRCS – Corporate Records Center System CRDM – Control Rod Drive Mechanism CRDR – Control Room Design Review CRDS – Corporate Records &

Documentation Services CREACUS – Control Room Emergency Air

Cleanup System CRESP – Control Room Emergency

Shutdown Panel CRIS – Control Room Isolation Signal CRIS – Control Room Isolation System CRO – Cathode·ray oscilloscope CRS – Contract Reporting System

CRS – Control Room Supervisor CRS – Coolant Radwaste System CRT – Cathode-ray tube CS – Containment Spray CS – Construction Specifications C/S – Cost and Schedule, Civil/Structural c/s – cycle per second CSA – Construction Safety Assessment CSAS – Containment Spray Actuation

SignalC/S-C – Contractor/Subcontractor CSE – Construction Safety Evaluation CSNI – Committee on the Safety of Nuclear

InstallationsCSP – Containment Spray Pump CSPE – chlorosulfonated polyethylene

jacketCSS – Containment Spray System CST – Condensate Storage Tank CT – Calibration Test CT – Current Transformer CTAC – Customer Technology Applications

CenterCTMT -- Containment CTO – Construction Turnover CTRS – Coordinated Tactical Radio

SystemCV – Control Valve CV – Cleanness Verification Procedure

FlushCVCM – Cleanliness Verification and

Control Manual CVCS – Chemical Volume Control System CW – continuous wave CWA – Contractor Work Assignment CWO – Construction Work Order CWP – CEA Withdrawal Prohibit CWS – Circulating Water System

DDAS – Data Acquisition System DASS – Disturbance Analysis Surveillance

SystemDAW – Dry Active Waste

ACRONYMS

E- 6

dB – decibel dBA – decibel (ambient) DBA – Design Basis Accident DBD – Design Bases Document(ation) DBE – Design Basis Earthquake DBE – Design Basis Event dBm – decibel referred to one milliwatt DBMS – Data Base Management System DC – Design Calculation DC – Design Change dc – direct current DCC – Distributed Computer Control DCD – Design Criteria Document DCD – Document Control Desk (Hqtrs,

USNRC) DCM – Design Criteria Manual DCMS – Document Control Management

SystemDCN – Design Change Notice DCN – Drawing Change Notice DCP – Design Change Package DCS – Dry Cask Storage DDM – Duty Division Managers (SONGS) DDN – Document Deficiency Notice DDSMS – Digital Dispatch Security

Monitoring System DECON – Decontamination DEG – Data Engineering Group deg – degree (temperature interval or

difference) / ° degree (plane angle) °C – degree Celsius °F – degree Fahrenheit °K – degree Kelvin °R – degree Rankine DEIS – Draft Environmental Impact

StatementDEO – Design Engineering Organization DER – Deficiency Evaluation Report DFG – Dry Flue Gas DG – Diesel Generator (Units 1, 2 and 3) DGP – Data Gathering Panel DHS – Department of Health Services

(California) dia(m) – diameter DIMPLS – Dosimetry Processing

Laboratory System (NIS)

DLMS – Draindown Level Monitoring System

DM – NEDO Discipline Manager DNA – Does Not Apply DNB – Departure from Nucleate Boiling DNBR – Departure from Nucleate Boiling

Ratio; Pred Heat Flux/Actual Heat Flux DOE – Department of Energy DOHS – Department of Health Services DOT – Department of Transportation

(federal)DR – Daily Report for Security Officers DRA – Division of Ratepayer Advocates (of

the PUC) DRADM – Design Review & Approval

Distribution Matrix DRADM – Document Review & Approval

Distribution Matrix DRC – Document Review Committee DRD – Direct-Reading Dosimeter (NRC) DRM – Design Review Meeting DRN – Document Review Notice DRRM – Design Review Responsibility

Matrix DSAR – Defueled Safety Analysis Report DSB – double sideband DSC – Dry Shielded Canisters DSD – Dedicated Safe Shut Down DSP – Digital Signal Processing DSRO – Division of Safety Review and

Oversight (NRC) DSS – Dedicated Safe Shutdown System DSS – Drug Screening System (NIS) DTC – Dose Tracking Card DVM – Digital Volt Meter DVR – Design Verification Release Dwg – Drawing DWP – Department of Water & Power dyn – dyne

EE & TS – Engineering & Technical Services EA – Emergency Advisor (TSC) EAB – Exclusion Area Boundary

ACRONYMS

E- 7

EAF – Equivalent Availability Factor EAL – Emergency Action Level EARS – Emergency Assessment and

Response System Aut - Automatic Mode Man - Manual Mode

EASI – Easy Access Systems Interface (NIS)

EBS – Emergency Broadcast System (Public Notification)

EC – Emergency Coordinator (TSC) E-C – Engineer-Constructor E&C – Engineering and Construction EC – Equipment Control ECAC – Energy Cost Adjustment Clause ECAD – Electrical Characterization and

Diagnostics ECC – Energy Control Center ECCS – Emergency Core Cooling System ECDP – Engineering and Construction

Department Procedure (/Policy) ECL – Emergency Classification Level

(NRC)ECN – Engineering Change Notice ECP – Engineering Change Package ECSA – Electrical Conductor Seal

AssemblyECT – Eddy Current Testing EDDIE – Electronic Document Delivery &

Information Exchange EDG – Emergency Diesel Generator EDM – Engineering Data Management OR

Engineering Documentation Management

EDMR – Equipment Deficiency Mode Restraint (Tech Specs)

EDMS – Engineering Documentation Management System

EDNA – Edison Digital Navigation Agent EDO – Engineering Design Organization EDO – Executive Director for Operations

(Hqtrs. USNRC) EDP – electronic data processing E&E – Effluent and Environmental EEG – electroencephalograph EEI – Edison Electric Institute

EEIL – Emergency Equipment Inventory List

EEM – Exercise Evaluation Method (NRC) EEQ – Environmental Equipment

Qualification EER – Engineering Evaluation Report EF – Effluent Monitoring EF – E-Field EFAS – Emergency Feedwater Actuation

SignalEFPD – Effective Full Power Days EFPH – Effective Full Power Hours EG – Engineering (Identifier) EGL – Emergency Group Leader (OSC) EGS – Engineering Group Supervisor EHC – Electro-Hydraulic Control EHF – extremely high frequency ehv – extra·high voltage EI – Energy, Inc. EIR – Environmental Impact Report EIS – Environmental Impact Statement EKG – electrocardiograph ELF – extremely low frequency ELP – Engine Local Panel EMC – electromagnetic compatibility EMMP – Environmental Monitoring

Protection Plan EMF – electromotive force EMI – Electromagnetic Interference EMMP – Environmental Monitoring

Protection Plan EMSA – Emergency Medical Services

Agency (NRC) EMT – Emergency Medical Technician EMU – electromagnetic unit EN – Environmental ENC – Emergency News Center (NRC) ENF – Event Notification Form ENS – Emergency Notification System

(NRC)EOC – Emergency Operations Center OR

End of Cycle EOD – Explosive Ordnance Disposal EOF – Emergency Operations Facility

(NRC)EOI – Emergency Operating Instruction

ACRONYMS

E- 8

EOL – End of Life EOP – Emergency Operating Procedure EP – Emergency Plan EP – Emergency Preparedness EPA – Electrical Penetration Assemblies EPA – Environmental Protection Agency EPB – Emergency Planning Bulletin EPC – Emergency Planning Coordinator

(TSC)EPG – Emergency Procedure Guidelines EPIP – Emergency Plan Implementing

Procedures EPP – Environmental Protection Plan EPPE – Evaluating Potential Problem

EquipmentEPPM – Essential Plant Parameters

MonitoringEP&R – Engineering, Planning and

ResearchEPR – ethylene propylene rubber insulation EPRI – Electric Power Research Institute EPSAC – Emergency Planning Subject

Area Committee EPTG – Emergency Procedure Technical

Guidelines EPZ – Emergency Planning Zone

(Emergency Sheltering/Evacuations) EQ – Environmental

Qualification/Environmentally Qualified EQCN – Environmental Qualification

Change Notice EQDB – Equipment Data Bank EQDP – Environmental Qualification Data

PackageEQML – Environmental Qualification Master

ListER – Environmental Report ERA – Economic Regulatory Administration ERF – Emergency Response Facility ERFDADS – Emergency Response

Facilities Data Acquisition and Display System

erg – erg ERG – Emergency Response Guidelines ERIN – Emergency Response Information

Network (NIS)

EROLS – Environmental Report Operating License Stage

ERP – Engineering Review Process ERP – Emergency Response Personnel ERTD – Emergency Response Telephone

DirectoryERTEC – PVNGS/Environmental

ConsultantESC – Engineering Services Contractor ESF – Engineered Safety Features ESFAS – Engineered Safety Feature

Actuation System ESFS – Engineered Safety Feature System ESI – Equilibrium Shape Index ESM – Edison (Employee) System of

Manuals ESO – Emergency Services Officer ESO – Emergency Support Organization ESOP – Employee Stock Ownership Plan ESR – Engineering Site Representative ESU – electrostatic unit ETA – Estimated Time of Arrival ETC – Estimated Time of Completion EWO – Engineering Work Order eV – electron volt EVSD – Evacuation Shutdown Panel

FFAMM – Fuel and Material Management FAR – Field Action Request FBI – U.S. Department of Justice, Federal

Bureau of Investigation FBRIR – Fire Barrier Removal/Installation

Report [Outdated since 3/88, now known as "IFFRA" Impairment Form-Fire Rated Assembly]

FBRRR – Fire Barrier Removal and Reinstallation Report [Outdated since 3/88, now known as "IFFRA" Impairment Form-Fire Rated Assemblies]

FC – Flow Constant fc – footcandle FC – Forecast

ACRONYMS

E- 9

FCC – Federal Communications Commission

FCE – Facility Change Evaluation FCN – Facility Change Notice FCN – Field Change Notice FCR – Field Change Request FCV – Flow Control Valve FDC – Forms Distribution Center FEIS – Final Environmental Impact

StatementFEMA – Failure Effects & Mitigation

Analysis FEMA – Federal Emergency Management

Agency (NRC) FERC – Federal Energy Regulatory

CommissionFES – Final Environmental Statement FET – field effect transistor FFAP – Full-Face Air-Purifying Respirator FFAS – Full-Face Air-Supplying Respirator FFCPD – Full Flow Condensate Polisher

Demineralizer System FGIDCD – Field Generated Interim Design

Change Notice FHA – Fire Hazards Analysis FHIS – Fuel Handling Isolation Signal FHS – Fuel Handling System FID – Field Information Data FIDAS – Fixed In-core Detector Amplifier

SystemFIDCN – Field-generated Interim Design

Change Notice fL – footlambert FM – frequency modulation FME – Foreign Material Exclusion FMEA – Failure Modes & Effects Analysis FMEA – Foreign Material Exclusion Area FMT – Field Monitoring Team (NRC) FOA – Field Office Administrator FOAK – First of a Kind FOCUS – Focus Programming Support FOSAR – Foreign Object Search &

RetrievalFP – Fire Protection (Identifier) FP – Fission Products FPER – Fire Protection Evaluation Report

FPIS – Fire Protection Information System FPS – Fire Protection System FRG – Functional Recovery Guideline FRMAC – Federal Radiological Monitoring

and Assessment Center (NRC) FS – Fail-Safe FSA – Final Safety Analysis FSAR – Final Safety Analysis Report FSK – frequency-shift keying ft – foot ft/min – feet per minute ft2 – square foot ft3/min – cubic feet per minute ft/s – feet per second ft·lbf – foot pound·force ft·pdl – foot poundal FTA – Fault Tree Analysis FTT – Fuel Transfer Tube FUA – Fuel Use Act FUN – Follow-Up Notification (NRC Report

Form)FW – Feedwater FWIS – Feedwater Isolation Signal FWS – Feedwater System FWCS – Feedwater Control System Fxy – Planar Radial Peaking Factors;

subscript x - calculated FYI – For Your Information

Gg – gram G – gauss GADS – Generating Availability Data

Systemgal – gallon gal/min – gallons per minute Gb – gilbert GE – General Electric GE – General Emergency ECL (Declared

Emergency) (NRC) GEC – General English Controls GED – Generation Engineering and Design GEN – Generator

ACRONYMS

E- 10

GET – General Employee Training (Red-Badge Training)

GeV – gigaelectronvolt GHz – gigahertz GL – Group Leader GM – Geiger-Müller (NRC) GO – General Office (GO 1, 2, 3 and 4,

Corporate Headquarters) GP – General Physics GP – General Procedure GPI – Glass Packaging Institute GPM – Gallons per Minute (gal/min

preferred)GPS – General Performance Standards GPU – General Public Utilities GRC – General Rate Case GRIP – Generation Related Improvement

ProjectsGRS – Gaseous Radwaste System GS – NEDO Group Supervisor GSA – General Services Administration GT – Generic Test

Hh – hour H – henry HED – Human Engineering Discrepancy HELB – High Energy Line Break HELBA – High Energy Line Break Analysis HEPA – High Efficiency Particulate Air Filter HF – high frequency HF – Human Factors HFMUD – High Flow Makeup Demineralizer HFP – Hot Full Power HHL – Home Hot Line (EP) HJTC – Heated Junction Thermocouple HLSI – Hot Leg Safety Injection HP – Health Physics hp – High Pressure hp – horsepower HPCS – Health Physics Computer System HP&E – Health Physics and Environmental HPES – Human Performance Evaluation

System

HPL – Health Physics Leader (TSC) HPS – Hassayampa Pumping Station HPS – Health Physics Society HPSI – High Pressure Safety Injection HSC – Headquarters Support Center (EOF) HSWS – High Specific Waste Holding HTGR – High Temperature Gas Reactor Htr – Heater HV – Hand or Control Valve HV – high voltage HVAC – Heating, Ventilation, and Air

ConditioningHX – Heat Exchanger Hz – hertz

IIACS – International Annealed Copper

StandardIAEA – International Atomic Energy Agency I&C – Instrument and Calibration I&C – Instrumentation and Control IC – Integrated Circuits ICBO – International Conference of Building

OfficialsICC – Inadequate Core Cooling ICC – Interstate Commerce Commission

(federal)ICCN – Interim Calculation Change Notice ICEA – Insulated Cable Engineers

AssociationICI – In-Core Instrumentation ICN – Interim Calculation Notice ICRP – International Commission on

Radiological Protection ICS – Integrated Control System ID – Identification (Number) ID – inside diameter IDCN – Interim Design Change Notice IDCN – Interim Drawing Change Notice IDLH – Immediately Dangerous to Life and

HealthIDR – Interdisciplinary Review IDS – Intrusion Detection System

ACRONYMS

E- 11

IE – Inspection and Enforcement (HQTRS USNRC)

I&E – Inspection and Enforcement IEAL – International Energy Associates

LimitedIEB – Inspection and Enforcement Bulletin

(Issued by NRC) IEEE – Institute of Electrical and Electronic

Engineers IE&MS – Industrial Engineering &

Management Services IEN – Information/Enforcement Notice IF – intermediate frequency IFFRA – Impairment Form-Fire Rated

AssemblyIID – Imperial Irrigation District IIS – Integrated Implementation Schedule IIT – Incident Investigation Team (NRC) ILS – Integrated Living Schedule ILRT – Integrated Leak Rate Test in. – inch in./s – inch per second in.2 – square inch INCA – In-Core Analysis INPO – Institute of Nuclear Power

OperationsIOC – Irvine Operations Center IOE – Industry Operating Experience IOEE – Industry Operating Experience

EvaluationIPC – Interjurisdictional Planning

Committee (NRC) IPCEA – Insulated Power Cable Engineers

AssociationIPDR – Inspection Planning Data Report IPRE – Integrated Plant Review Engineer IPZ – Ingestion Pathway Zone IR – infrared IRE – Independent Review Engineer IS – Information Services (Department) IS – Industrial Safety (Identifier) ISA – Instrument Society of America ISEG – Independent Safety Engineering

GroupISEG – Independent Safety Evaluation

Group

ISF – Industrial Security Force (Station Security)

ISFSI – Independent Spent Fuel Storage Installation

ISI – In-Service Inspection ISM – Independent Study Module ISO – Independent System Operator ISR – Independent Safety Review IST – In-Service Test (pumps/valves) ITC – Isothermal Temperature Coefficient ITS – Important to Safety IWP – Interim Work Procedure

JJ – joule J/deg – joules per degree J/°K – joules per degree Kelvin JCO – Justification for Continued Operation JOIS – Job Opportunity Information System JPM – job performance measurement JS – Job Section

Kk_ – kilohm kc/s – kilocycles per second keV – kiloelectronvolt kg – kilogram kG – kilogauss kgf – kilogram·force kHz – kilohertz kJ – kilojoule KI – Potassium Iodide km – kilometer km/h – kilometers per hour KMC – No Literal Definition KSA – Knowledge, Skills and Abilities kV – kilovolt kVA – kilovoltampere kvar – kilovar kW – kilowatt kWh – kilowatthour

ACRONYMS

E- 12

LL – lambert l – liter l/s – liters per second La – Max Containment Accident Leakage at

Pa -- %/24 hr. LA – Lightning Arrester Lam – Measured containment leakage at

Pa LAN – Local Area Network lb – pound lbf – pound·force lbf·ft – pound·force·foot lbf/in2 – pounds·force per square inch psi – pound per square inch LBLOCA – Large Break Loss-of-Coolant

Accident LC – Inductance-Capacitance circuit LC – Locked Closed LCL – Licensing Commitment List LCO – Limiting Condition for Operation

(Tech Specs) LCOAR – Limiting Condition for Operation

Action Requirement(Tech Specs) LCP – Limited Change Package LCS – Licensee Controlled Specifications Ld – Design Containment Leakage at Pa --

%/24 hr. LEA – Law Enforcement Agency LEA – Low Excess Air LEL – Lower Explosive Limit LER – Licensee Event Report LER – Licensing Event Report LETS – LCOAR and EDMR Tracking

System (NIS) LF – low frequency LFAS – Loose-Fitting Air-Supplying

Respirator LIS – Licensing Information Services LLRT – Local Leak Rate Test LLRWM – Low-Level Radioactive Waste

Managementlm – lumen lm/ft2 – lumens per square foot

lm/m2 – lumens per square meter lm/W – lumens per watt lm·s – lumen second ln – logarithm, natural LNG – Liquified Natural Gas LO – Locked Open LOCA – Loss-of-Coolant Accident log – logarithm, base 10 LOOP – Loss of Offsite Power LOP – Leadership Observation Program LOP – Loss of Power LOVS – Loss of Voltage Signal LP – Low Pressure LPD – Local Power Density LPMS – Loose Parts Monitoring System LPSI – Low Pressure Safety Injection LRCF – Low Reactor Coolant Flow Bypass LS – Limit Switch LSSS – Limiting Safety System Settings Lt – Max Containment Leakage at Pt LTA – Lost Time Accident LTC – Load Tap Changer Ltm – Measured containment leakage at Pt LTOP – Low Temperature Over Pressure

ProtectionLV – Low Voltage LWR – Light Water Reactor lx – lux

M...' – minute (plane angle) ..." – second (plane angle) μA – microampere μF – microfarad μg – microgram μH – microhenry μm – micrometer μ – micron (the name micrometer ( μm ) is

preferred)μs – microsecond μS – microsiemens μW – microwatt mi/h – mile per hour mi – mile (statute)

ACRONYMS

E- 13

mil – mil m – meter m – megohm m2 – square meter m3 – cubic meter m3/s – cubic meters per second mA – milliampere mg – milligram mH – millihenry ml – milliliter mm – millimeter mmHg – millimeter of mercury,

conventionalms – millisecond mS – millisiemens mV – millivolt mW – milliwatt Mc/s – megacycles per second MeV – megaelectronvolt MHz – megahertz MV – megavolt MW – megawatt MWe – megawatt electric MWt – megawatt thermal MA – Maintenance (Identifier) MAA – Material Access Area MAAC – Major Additions & Adjustments

Clause MAT – Material Acquisition Team MCC – Motor Control Center MCCB – Molded Case Circuit Breaker MCR – Main Control Room MED – Management Experience

Development (Program) MEL – Master Equipment List MELBA – Moderate Energy Line Break

Analysis MEMR – Marine Environmental Monitoring

ReportMET – Meteorological MF – medium frequency MFBV – Main Feedwater Bypass Valve MFCV – Main Feedwater Control Valve MFIV – Main Feedwater Isolation Valve MFWCS – Main Feed Water Control

System

MFWP – Main Feedwater Pump MFWS – Main Feedwater System MG – Motor Generator MHD – magnetohydrodynamics mho – mho MHW – Mean High Water (Pacific Ocean) MICDS – Moveable In-Core Detector

Systemmin – minimum min – minute (time) MKS – meter·kilogram·second MLO – Main Lube Oil MLWS – Miscellaneous Liquid Waste

SystemMMF – magnetomotive force MMI – Man Machine Interface MMO – Material Management Organization MMP – Minor Modification Package MMPI – Minnesota Multiphasic Personality

InventoryMMS – Material Management System MO – Maintenance Order MOG – Motor Operated Gate MOS – metal oxide semiconductor MOSAIC – Maintenance Operations Station

Technical & Administration Integrated Computer System

MOU – Memorandum of Understanding MOV – Motor Operated Valve MOVATS – Motor Operated Valve Analysis

and Testing System MPC – Maximum Permissible

ConcentrationMPE – Multiple Position Extensometer MPHF – Multi-Purpose Handling Facility MPO – Master Purchase Order MPOB – Maximum Permissible Organ

BurdenMR – Millirem MRC – Marine Review Committee MS – Main Steam MS – Material Support (Identifier) MSA – Material/Service Authorization MSA – Mine Safety Appliance M&SD – Management and Supervisor

Development (Program)

ACRONYMS

E- 14

MSDS – Material Safety Data Sheets (OSHA Div.)

MSIS – Main Steam Isolation Signal MSIV – Main Steam Isolation Valve MSLB – Main Steam Line Break MSLBA – Main Steam Line Break Accident MSR – Moisture Separator Reheater MSS – Main Steam System MS-SONGS – Material Services-San

Onofre Nuclear Generating Station MSSV – Main Steam Safety Valve MTBF – Mean Time Between Failure MTC – Moderator Temperature Coefficient MTE – Measuring and Test Equipment M&TE – Measuring and Test Equipment MTO – Material Takeoff MTS – Master Tracking System MUD – Makeup (Water) Demineralizer m/w -- manway MW – Microwave MWS – Miscellaneous Waste Holding Mx – maxwell

NN – newton N·m – newton meter N/m2 – newtons per square meter nA – nanoampere nF – nanofarad nm – nanometer ns – nanosecond nW – nanowatt NAC – National Assurance Corp. (NAC-ID-

model number) NATS – Non-regulatory Acton Tracking

SystemNA&EP – Nuclear Affairs and Emergency

PlanningNARC – Nuclear Audit and Review

CommitteeNARUC – National Association of

Regulatory Utility Commissioners NAS – National Aircraft Standards NAWAS – National Warning System (NRC)

NBA – Nuclear Business Administration NC – Normally Closed NC – Nuclear Construction NCB – Nuclear Control Board NCC – Network Control Center NCDB – Nuclear Consolidated Data Base NCE – Nuclear Construction Engineer NCR – Non-Conformance Report NCRS – Non-Conformance Reporting

SystemNCV – Non-Cited Violation NDE – Nondestructive Examination NDL – Nuclear Data Link NDMS – Nuclear Document Management

SystemNE – Nuclear Engineering (files) NEA – Nuclear Energy Agency NEA – Nuclear Engineering Administration NE&C – Nuclear Engineering &

ConstructionNEDO – Nuclear Engineering Design

OrganizationNEDOTRAK – Nuclear Engineering Design

Organization Tracking System NEDS – Nuclear Employment Data System NEI – Nuclear Energy Institute NEMA – National Electrical Manufacturers

AssociationNEOCR – Nuclear Engineering &

Operations Commitment Register - Station

NEPA – National Environmental Policy Act NERC – North American Electric Reliability

Council NERT – Nuclear Emergency Response

TeamNES&L – Nuclear Engineering, Safety &

Licensing NESHAPS – National Emissions Standards

for Hazardous Air Pollutants NFM – Nuclear Fuel Management NFPA – National Fire Protection

AssociationNFS – Non-Fail Safe NFS – Nuclear Fuel Supply NGS – Nuclear Generation Site

ACRONYMS

E- 15

NI – Nuclear Instrumentation NIS – Nuclear Information Services (aka

"IF" Identifier) NIS – Nuclear Instrument System NIST – National Institute of Standards and

TechnologyNL – Nuclear Licensing NLFS – Nuclear Licensing Filing System nmi – nautical mile NML – Nuclear Mutual Limited NMSS – Nuclear Material Safety and

Safeguards (Hqtrs USNRC) NNI – Non-Nuclear Instrumentation NO – Normally Open NO – Nuclear Operations Order No. – Number NOA – Nuclear Operations Assistant (Shift

Communicator)NOA – Nuclear Oversight & Assessment NOD – Nuclear Oversight Division NOI – Normal Operating Instruction NOI – Notice of Intention NOMIS – Nuclear Operation and

Maintenance Information Services NOUE – Notification of Unusual Event ECL

(NRC)NOV – Notice of Violation Np – neper NP – Negative Pressure Respirator NPDES – National Pollution or Pollutant

Discharge Elimination System NPEAC – Nuclear Power Executive

Advisory Committee NPEO – Nuclear Plant Equipment Operator NPG – Nuclear Procedures Group NPOC – Nuclear Power Oversight

CommitteeNPRC – National Personnel Records

Center (Bi-Military Service) NPRDS – Nuclear Plant Reliability Data

SystemNPSH – Net Positive Suction Head NQC – Nuclear Quality Control Department NRA – Nuclear Regulatory Affairs NRC – Nuclear Regulatory Commission NR&P – Nuclear Rates & Planning

NRPP – Non-Radiological Industrial Respiratory Protection Program

NRR – Nuclear Reactor Regulation (Hqtrs USNRC)

NRR – Nuclear Rate Regulation (P. B. Klapka's group)

NRRPT – National Registry of Radiation Protection Technologists

NSAC – Nuclear Safety Analysis Center NSC – Nuclear Safety Concern NSC – Nuclear Services Corporation NSE – Nuclear Systems Engineer(ing) NSG – Nuclear Safety Group NSR – Nonsafety Related NSRFP – Nuclear Non-Safety Related Fire

ProtectionNSSS – Nuclear Steam Supply System NTD – Nuclear Training Division NTIS – National Technical Information

Service NTOL – Near Term Operating License NUMARC – Nuclear Management and

Resources Council NUREG – Nuclear Regulatory Information

Guidelines (not "Regulations") NUS – Nuclear Utility Service NuSG – Nuclear Section Guide NUTAC – Nuclear Utility Task Action

CommitteeNVAF – North Vehicle Access Facility NVLAP – National Voluntary Laboratory

Accreditation Program NWPA – National Waste Policies Act NWTS – Nuclear Work Tracking System

OOAC – Operational Area Coordinator (NRC) OBE – Operating Basis Earthquake OC – Originating Contractor OCA – Owner-Controlled Area (East of I-5,

Mesa, and West of I-5) OCB – Oil Circuit Breaker OCC – Outage Control Center OCEOC – Orange County EOC (NRC)

ACRONYMS

E- 16

OCFD – Orange County Fire Department (NRC)

OCTSP – Operations Surveillance Tracking & Scheduling Program (NIS)

OD – outside diameter ODAC – Offsite Dose Assessment Center

(EOF)ODAC – Overall Dose Assessment

Calculation ODCM – Offsite Dose Calculation Manual ODER – Operations Division Experience

ReportODP – Office of Disaster Preparedness

(NRC)Oe – oersted OEE – Operating Experience Evaluation OEES – Onsite Emergency Evacuation

SystemOEF – Operational Experience Feedback

Information OERP – Offsite Emergency Response

Plan(s)OES – Office of Emergency Services

(California) OGC – Office of the General Council (NRC) OIC – Officer in Charge (NRC) OII – Order Instituting Investigation OIR – Open Item Report OJT – On-the-Job Training OL – Operating License O&M – Operations and Maintenance O&MS – Operations and Maintenance

SupportOMD – Outage Management Division OMR – Open Market Recycle -- Fuel

Management Plan using Plutonium as a fuel

OMS – Reactor Overpressure Mitigating System

ONL – Onsite Nuclear Licensing OP – Operations (Identifier) OPB – Operating Plant Budget OPG – Operations Procedures Group OPI – Open Permissive Interlock Ops – Operations OCR – Optical Character Recognition

OR – Operational Experience Review ORE – Occupational Radioactive Exposure ORP – Operator Requalification Program OSC – Operational Support Center or

OscillographOSC – Operations Support Center (Unit 1

and Units 2/3 OS&D Over, Short or Damaged)

OSHA – Occupational Safety and Health Act

OSHA – Occupational Safety Health Administration

OSRC – Onsite Review Committee OSS – Operations Shift Superintendent of

the Affected Unit (Unit 1 and Units 2/3) OTAG – Overtime Trend Analysis Graphics OTC – Official Test Copy OTR – Overtime Reporting Systems (NIS) oz – ounce (avoirdupois) OZD – Offshore Zone of Deformation

PPa – Peak Accident Pressure (containment) PA – Power Ascension PA – Project Administrator PA – Process Assessment PA – Protected Area (SONGS 123) pA – picoampere PAX – Edison Private Automatic Exchange pF – picofarad ps – picosecond pW – picowatt PAC – Planning and Control PAD – Protective Action Decision (NRC) PAG – Protective Action Guide (NRC) PAM – Pulse·amplitude modulation PAMI – Post Accident Monitoring

InstrumentationPAMM – Procurement and Material

ManagementPAP – Program Area Plan PAR – Protective Action Recommendation

(EP)PASS – Post-Accident Sampling System

ACRONYMS

E- 17

PAX – Private Automatic Exchange (SCE) PBX – private branch exchange PC – Personal Computer (NIS) PC – Proposed Changes PCA – Plant Change Authorization PCB – Power Circuit Breaker PCM – pulse code modulation PCM – pulse count modulation PCN – Procedure Change Notice (SCE) PCN – Procurement Change Notice

(Bechtel)PCO – Procurement Change Order PCO – Purchase Change Order PCP – Process Control Program PCS – Plochere Color Standard PD – Project Directive PDIL – Power Dependent Insertion Limits pdl – poundal PDM – pulse duration modulation PDR – Public Document Room (NRC) PDS – Personnel Database System (NIS) PDTS – Permanently Defueled Technical

SpecificationPE – Preoperational Test PE – Procurement Engineer(ing) PE – Project Engineer PEA – Preliminary Environmental

AssessmentPEB – Pre-Engineered Building PEDMS – Plant and Equipment Data

Management System PEL – Permissible Exposure Limit PEO – Plant Equipment Operator PEP – Preliminary Engineering Package,

Procurement Engineering Package PERC – Plant Expenditure Review

CommitteePERT – Plant Emergency Response

TelephonePEZ – Public Education Zone (Emergency

Sheltering)PF – power factor PF – Procedure, Form and Order Control PF – Protection Factor (Emergency

Planning) PFC – Proposed Facility Change

PFCP – Proposed Facility Change Package PFE – Project Field Engineer (Bechtel) PG&E – Pacific Gas & Elecric Company PGP – Procedures Generation Package PHQ – Personnel History Questionnaire

(BI)PI – Pressure Indicator PIC – Pocket Ion Chamber (HP) PIC – Pen (and) Ink Change P&ID(s) – Piping and Instrumentation

Diagram(s)/ Drawing(s) PIO – Public Information Officer (NRC) PIP – Productivity Improvement Program PIFUA – Power Plant & Industrial Fuel Use

ActPIR – Problem Investigation Request PIV – Post Indicator Valve (fire protection) PLCEA – Part Length Control Element

AssemblyPLCEDM – Part Length Control Element

Drive Mechanism PLCS – Pressurizer Level Control System PLHGR – Peak Linear Heat Generation

RatePM – phase modulation, Preventative

Maintenance, Project Manager PMB – Preventive Maintenance Bases PMEP – Productivity & Measurement

Effectiveness Plan PMF – Probable Maximum Flood P&MM – Procurement and Material

ManagementPMO – Post-Maintenance Operability PMO – Preventative Maintenance

OptimizationPMO – Project Management Organization PMO – Provost Marshall Office (Camp

Pendleton)PMP – Procedure Modification Permit PMRC – Plant Modification Review

CommitteePMS – Plant Monitoring System PNAA – Prompt Neutron Activation

Analysis PNEU – PneumaticPO – Post Order

ACRONYMS

E- 18

PO – Purchase Order POL – Provisional Operating License PORV – Power Operated Relief Valve POV – Power Operated Valve pp – pump PP – Positive Pressure Respirator PPCA – Proposed Plant Change

AuthorizationPPCS – Pressurizer Pressure Control

SystemPPDI – Plant Process Display

InstrumentationPPE – Principal Project Engineer ppm – Parts per million PPM – pulse position modulation PPS – Plant Protection System PR – Periodic Review PRA – Peak Recording Accelerographs PRA – Probabilistic Risk Assessment

(NRC)PRA – Public Risk Assessment PREQ – Procurement Requisition PRF – pulse·repetition frequency PRIDE – Performance, Recognition,

Innovation, Dedication and Excellence (SCE)

PRINT – Printing and VAX Computer Operations

PRR – pulse repetition rate PRR – Problem Review Report PRR – Procedure Resolution Request PSAR – Preliminary Safety Analysis Report PS – Post-Accident Sampling PS – Power Supply PSAR – Preliminary Safety Analysis Report PSCG – Physical Security Coordinating

GroupPSD – Prevention of Significant

DeteriorationPSE – Pre-Service Examination psi – pounds per square inch psia – pounds per square inch, absolute psid – pounds per square inch, differential psig – Pounds per Square Inch Gauge PSP – Physical Security Plan (SONGS

123)

Pt – Containment Pressure for Type A Tests

PT – Potential Transformer PTM – pulse·time modulation PTS – Pressurized Thermal Shock PUC – Public Utilities Commission

(California) PURPA – Public Utility Regulatory Policies

ActPVNGS – Palo Verde Nuclear Generating

Station PWA – Project Work Assignment PWEE – Preliminary Work Element

EstimatePWM – pulse·width modulation PWR – Pressurized Water Reactor (Units

123)PX – Power Exchange Pzr – Pressurizer

QQA Quality Assurance QAE Quality Assurance Engineer QAIS Quality Assurance Information

SystemQAM Quality Assurance Manual QAP Quality Assurance Procedure QC Quality Control, Quality Class QCI Quality Control Inspector OR

Quality Control Instruction QHP Quality Hold Point QRCL Quality-Related Commodity

ListQSPDS Qualified Safety Parameter

Display System

RR – roentgen r/min – revolutions per minute r/s – revolutions per second R&C – Reception and Care Center (NRC) R&D – Research and Development

ACRONYMS

E- 19

RAC – Regional Assistance Committee (NRC)

RACES – Radio Amateur Civil Emergency Services (NRC)

rad – radian RAD – Radiation Absorbed Dose RAER – Renewable/Alternative Energy

Resources RAS – Recirculation Actuation Signal RAQAT – Requisition Attachment-Quality

Assurance Technical Requirements RC – Reviewing Contractor RC – resistance capacitance RCC – Rod Control Cluster RCDT – Reactor Coolant Drain Tank RCM – Reliability Centered Maintenance RCP – Reactor Coolant Pumps,

Radiochemistry Program RCPB – Reactor Coolant Pressure

BoundaryRCRA – Resource Conservation &

Recovery Act RCS – Reactor Coolant System RCS – Rod Control System RCSS – Reactor Cycle Sampling System RCTS – Regulatory Commitment Tracking

SystemRCTS – Regulatory Compliance Tracking

SystemRDN – Receipt Deficiency Notice RE – Records Control RE – Responsible Engineer REM – Roentgen Equivalent Man REP – Radiation Exposure Permit REPP – Radiation Exposure Permit

Processing System RER – Radiation Exposure Report RER – Regulatory Effectiveness Review

(NRC)REV – Revision RF – radio frequency RFI – radio frequency interference RFI – Request for information RFO – Refueling Outage RGDC – Retrofit General Design Criteria RHR – Residual Heat Removal

RIC – Resistance Inductance Capacitance RIDR – Receiving Inspection Data Report RIMS – Redundant Instrument Monitoring

SystemRIN – Radiological Infraction Notice RIS – Regulatory Issue Summary RLWS – Radioactive Liquid Waste System RMO – Repetitive Maintenance Order rms – root mean square RMU – Reactor Make Up RMV – RemoveRMW – Reactor Makeup Water RO – Reactor Operator RP – Radiation Protection RP – Reliability and Performance RPE – Registered Professional Engineer RPR – Retrofit Problem Report RPS – Reactor Protection System RPS – Reactor Protective System R/R – Remove/Replace RR – Railroad R&R – Removed and Replaced RRG – Records Review Group RRS – Reactor Regulating System RSP – Reactor Shutdown Panel RSPI – Remote Shutdown Panel

Instrumentation (LO42) RSPT – Reed Switch Position Transmitter RSSDR – Raceway Support Supplemental

Data Report RT – Radiographic Testing RTB – Reactor Trip Breaker RTD – Resistance Temperature Detector RTO – Reactor Trip Override RTO – Responsible Test Organization RTP – Return To Power RTS – Return To Service RV – Region V (NRC) RV – Reactor Vessel RVLMS – Reactor Vessel Level Monitoring

SystemRWG – Repower Working Group RWLI – Refueling Water Level Indicator RWO – Responsible Work Organization RWR – Radwaste Condensate Return RWST – Refueling Water Storage Tank

ACRONYMS

E- 20

RWT – Refueling Water Tank RX – Reactor

S..." – second (plane angle) s – second S – siemens SAAS – Site Access Authorization System SAE – Site Area Emergency ECL (Declared

Emergency) (NRC) SAFDL – Specified Acceptable Fuel Design

LimitsSAIC – Science Applications International

CorporationSALP – Systematic Assessment of

Licensee Performance Report (NRC) SAM – Shape Annealing Matrix SAPA – Substance Abuse Program

AdministrationSAR – Safety Analysis Report SAS – SAS Programming Support SAS – Secondary Alarm Station SAS – Secondary Alarm System SAS – Statistical Analysis System SBCS – Steam Bypass Control System SBLOCA – Small Break Loss-of-Coolant

Accident SBO – Station Blackout SBVMWD – San Bernardino Valley

Municipal Water District SC – Shift Commander (On-Duty Security) SCAQMD – South Coast Air Quality

Management District SCAR – Security Corrective Action Request SCBA – Self-Contained Breathing

Apparatus SCE – Southern California Edison SCEPP – Southern California Earthquake

Preparedness Project SCMS – Simulator Configuration

Management System (NIS) SCN – Specification Change Notice SCP – Safeguards Contingency Plan

(SONGS 123)

SCR – silicon controlled rectifier SCRAM – Safety Control Rod Ax Man SCS – Security Computer System SCS – Shutdown Cooling System S/C/SC –

Supplier/Contractor/Subcontractor SCU – Statistical Combination of

UncertaintiesSDAC – State Dose Assessment Center

(NRC)SDAR – Security Division Audit Report SDC – Safety Display Console SDCL – Supplier Document Control Log SDCS – SCE Document Configuration

SystemSDCS – Shutdown Cooling System SDDR – Supplier Deviation Disposition

Requests SDE – System Design Engineer SDG&E – San Diego Gas & Electric

Company SDR – Supplier Disposition Request SDRWQCB – San Diego Regional Water

Quality Control Board SDS – Submerged Demineralizer System SDSS – Security Detection System

Specialist SE – Security (Identifier) SE – Security Event SEA – Safety Engineering Assessment SEB – Sphere Enclosure Building ..." – second (plane angle) SECDIV – Security Division SECON – Security Condition (Safeguards

Threat Situation) SED – Station Emergency Director (TSC) SEE – Substitute Equivalency Evaluation SEE-IN – Significant Event Evaluation and

Information Network - INPO SEN – Significant Event Notification (INPO) SEP – Site Emergency Preparedness SEP – Sphere Enclosure Project (Unit 1) SEP – Systematic Evaluation Program SER – Safety Evaluation Report - Issued by

INPO (or NRC) SER – Security Event Report

ACRONYMS

E- 21

SER – Significant Event Report (INPO) SERL – Station Emergency Recall List SFD – System Functional Description SFM – Site Facilities Maintenance SFP – Spent Fuel Pool SFR – Startup Field Report SFTA – System Function Task Analysis SG – Steam Generator(s) SGBS – Steam Generator Blowdown

SystemSGLC – Steam Generator Level Control SGTR – Steam Generator Tube Rupture SHF – superhigh frequency SI – Safeguards Information SI – Safety Injection SI – Seismic Interaction SIAS – Safety Injection Actuation Signal SIMPL – Safeguards Information

Management Personnel List SIR – Station Incident Report SIS – Safety Injection System SIS – Supplier Information System SISLOP – Safety Injection System

Actuation With Loss of Offsite Power SISS – SONGS Integrated Scheduling

SystemSIT – Safety Injection Tank SL – Security Leader (TSC) SLACS – Site Local Area Communication

SystemSLAN – Site Local Area Network SLB – Steam Line Break SLSS – Safeguard Load Sequencing

SystemSM – Shift Manager SMACNA – Sheet Metal & Air Conditioning

Contractors National Assoc. SMM – Subcooling Margin Monitor SMR – Software Modification Request SN – Special Nuclear Material Inventory

and Control SNE – Site Nuclear Engineering SNM – Special Nuclear Material SNR – signal "to" noise ratio SO – San Onofre SO – Security Officer

SOC – State Emergency Operations Center (NRC)

SOCR – San Onofre Commitment Register SOCR – San Onofre Commitment Report SOE – Sequence of Events SOER – Significant Operating Experience

Reports - INPO SOMMS – San Onofre Maintenance

Management System SONGS – San Onofre Nuclear Generating

Station SOP – Standard Operating Procedure SOR – Security Observation Report SOS – State of the System (Report) SOS – Security Officer Supervisor SP – Security Plan SP – Special Procedure SP – Specific Procedure SP – State Parks, Pendleton Coast Area SPCS – Steam & Power Conversion

SystemSPDS – Safety Parameter Display System SPDS – Site Procedures and

DocumentationSPEER – Substitution Part Equivalency

Evaluation Report SPEOC – State Parks EOC (NRC) SPF – Security Processing Facility SPMT – Spare Parts Management Team SPND – Self Powered Neutron Detector SPOR – SOMMS Purchase Order

Requisition SPR – Site/Startup Problem Report

(Engineering)SQRT – Seismic Qualification Review

TeamSQRT – Square Root Function ft2 – square foot in2 – square inch m2 – square meter yd2 – square yard SR – Safety Related sr – steradian S-R – Surveillance Requirement(s) (Tech

Specs)

ACRONYMS

E- 22

SRC – SONGS Radiation Control System (NIS)

SRCS – Station Radiation Control System SRM – Schedule of Requested

ModificationsSRO – Senior Reactor Operator SRP – Standard Review Plan SS – Stainless Steel SS – Security Supervisor SS – Shift Superintendent SSAB – SONGS Site Access Badge (OCA) SSAM – Shift Superintendent Accelerated

MaintenanceSSB – single sideband SSE – Safe Shutdown Earthquake SSEP – Site Specific Earthquake Program SSFA – Safety System Functional

AssessmentSSFI – Safety System Functional

InspectionSSFICA – Safety System Functional

Inspection Commitment Analysis SSG – Site Support Group SSID – Shop Services & Instrumentation

Division SSMS – Safety Status Monitoring System SSPP – Stock Savings Plus Plan SSS – Security Screening System SSS – Site Scheduling Support System

(NIS)SSS – Site Support Services ST – Special Test STA – Shift Technical Advisor STA – Station Telecommunications Area STAIRS – Storage and Information

Retrieval System STAR – Special Tools and Rigging STEC – Station Technical (NGS) STER – Startup Test Exception Report STGR – Steam Generator Tube Rupture SU – Startup SV – Solenoid Valve SEE – Substitution Equivalency Evaluation SVAF – South Vehicle Access Facility S/W – Scope of Work SW – short wave

SWC – Salt Water Cooling SWCP – Salt Water Cooling Pump SWCS – Salt Water Cooling System SWGR – Switchgear SWO – Station Work Order SWR – standing"wave ratio SWR – Station Work Request SWRCB – State Water Resources Control

Board

TT – Tesla TAGS – Tagout Administration and

Generation System TAIS – Training Administration and

Information System TB – Terminal Block Tc – Reactor Coolant Cold Leg

TemperatureTC – transverse electric TCF – Target Capacity Factor TCN – Technical Change Notice TCN – Temporary Change Notice TCN – Test Change Notice TCP – Traffic Control Plan (SONGS) TCP – Traffic Control Point (NRC) TD – Time Delay TDC – Time Delay to close TDD – Time Delay on Deenergizing TDE – Time Delay on Energizing TDO – Time Delay to Open TDS – Total Dissolved Solids TDS – Training Documentation System

(NIS)TEC – Technology for Energy Corporation TEC – Training and Education Center Tech Spec – Technical Specification TEL – Telecommunications TEM – transverse electromagnetic 10 CFR – Code of Federal Regulations,

Part 10 (Energy) TEPA – Track Environmental Protection

Agency TER – Technical Evaluation Report

ACRONYMS

E- 23

TER – Test Exception Report TFM – Temporary Facility Modification TFT – thin film transistor Tg – Azimuthal Power Tilt TG – Turbine Generator TGIS – Toxic Gas Isolation System THY – Thyroid TI – Test Instruction TIBS – Test Item Banking System TICN – Test Instruction Change Notice TIME – Timekeeping System (NIS) TL – Technical Leader (TSC) TLD – Thermoluminescent Dosimeter

(Badge)TLU – Total Loop Uncertainty TM – transverse magnetic TMI – Three-Mile Island TMS – Training Management System (NIS) TN – Nuclear Training (AKA "NTD") TNQ – Training & Qualification Plan TO or t/o – Turnover TP – Test Procedure TPC – Thermal Power Calibration

ConstantsTPCW – Turbine Plant Cooling Water TPCWS – Turbine Plant Cooling Water

SystemT&Q – SONGS 123 Security Force Training

and Qualification Plan TQAM – Topical Quality Assurance Manual TQRS – Training Qualification Reporting

System (NIS) TR – Test Relay TR – Topical Report TRCL – Trend Review Check List TRIMS – Training Records Information

Management System (NIS) TRR – Transfer and Replacement

Requests TS – Technical Specification(s) TS – Test Switch T/S – Transmission/Substation TSC – Technical Support Center (Units 1

and 2/3) TSIP – Technical Specifications

Improvement Project

TSO – Time Sharing TSP – trisodium phosphate TURN – Towards Utility Rate

Materialization TV – television TVI – television interference TVA – Tennessee Valley Authority TWA – Temporary Work Assignment

Program (Injured Edison Employee) TWC – The Wackenhut Corporation TWG – Test Working Group (Project

Internal Review) TWT – traveling wave tube

Uu – atomic mass unit (unified) UA – Unitized Actuator UARG – Utility Air Regulatory Group UBC – Uniform Building Code UDC – Utility Distribution Company UE – Unusual Event (Declared Emergency) UEL – Upper Electrical Limit UFHA – Updated Fire Hazard Analysis UFSAR – Updated Final Safety Analysis

ReportUGS – Upper Group Stop UGS – Upper Guide Structure UHF – ultrahigh frequency UHS – Ultimate Heat Sink UL – Underwriter's Laboratories UNPOC – Utility Nuclear Power Oversight

CommitteeUNWMG – Utility Nuclear Waste

Management Group UPS – Uninterruptible Power Supply USCEA – U.S. Council for Energy

Awareness USGS – United States Geological Survey USI – Unresolved Safety Issue (NRC) USJRWPA – Upper San Joaquin River

Water & Power Authority USMC – United States Marine Corps

(Camp Pendleton) USMS – United States Marshall Service

ACRONYMS

E- 24

USNRC – United States Nuclear Regulatory Commission

USQ – Unresolved Safety Question (50.59) USWAG – Utility Solid Waste Activity Group USWC – Unsafe Work Conditions USWP – Unsafe Work Practices USWPRS – U.S. Water and Power

Resources Service UT – Ultrasonic Testing UV – ultraviolet UVTA – Under-Voltage Trip Attachment UWUA – Utility Workers Union of America

VV -- volt V&V -- Verified & Validated VA -- Vertical Assessment VA -- Vital Area(s) (SONGS 123) VA -- voltampere VAR -- Volt Amps Reactive VCO -- voltage controlled oscillator VCT -- Volume Control Tank VDIR -- Vent, Drain or Instrument Root VETIP -- Vendor Equipment Technical

Information Program VFO -- variable frequency oscillator VHF -- very high frequency VISIONS -- Versatile Interactive Simulator

of Nuclear Systems (Computer Program)

VLCBX -- Very Large Computerized Branch Exchange

VLF -- very low frequency VLPMS – Vibration and Loose Parts

Monitoring System VOPT -- Variable Over Power Trip VPCN -- Vendor Print Change Notice VPL -- Vendor Print Log VRPP -- Vital Records Protection Program VRR -- Valve Relief Request VSB -- vestigial sideband VSWR -- voltage standing"wave ratio VTP -- Verification Test Procedure VTVM -- vacuum tube voltmeter

vu -- volume unit vv -- valve

WW -- watt W/A -- work authorization WAIS -- Work Authorization Information

System (NIS) WANO -- World Association of Nuclear

Operators (performance indicators now fall under WANO)

WAR -- Work Authorization Request W/sr -- watt per steradian W/(sr"m2) -- watt per steradian square

meterWb -- weber WBCS -- Warehouse Bar Code System WBD -- Whole Body Dose WCC -- Woodward Clyde Consultants WD -- Wiring Diagram WDR -- Whole Document Revision WGIS -- Work Grouping Information

System (NIS) Wh -- watthour WHS -- Warehouse WIIS -- Warehouse Inventory Inquiry

SystemWNCR -- Warehouse Nonconformance

ReportWNF -- Work Notification Form WO -- Work Order WOG -- Water, Oil, or Gas service (valves

& fittings) WOG -- Westinghouse Owners Group w/out -- without WP -- Work Procedure (SONGS Nuclear

Construction)WPOA -- Wind Project Opportunity

AnnouncementWPP/QCI -- Work Plan Procedures/Quality

Control Instructions (Bechtel) WPTO -- Work Package Turnover WR -- Work Request WRCB -- Water Resources Control Board WRF -- Water Reclamation Facility (CPUC) WRGM -- Wide-Range Gas Monitor

ACRONYMS

E- 25

WRN -- Work Request Number WRWG -- Water Rights Working Group WTB -- Westinghouse Technical Bulletin

XXFCR -- Field Change Request (Initialed by

Construction)XFR -- Transfer

YYd -- yard yd2 -- square yard

ZZOI -- Zone of Influence

Declaration of Henry Weissmann

�

��

BEFORE THE PUBLIC UTILITIES COMMISSION OF THE

STATE OF CALIFORNIA

��

��

!��"�� #$ ��%& ��$�&��'��()%*�(+#)��,��$��

�

��(��(��

DECLARATION OF HENRY WEISSMANN IN SUPPORT OF SOUTHERN CALIFORNIA EDISON COMPANY’S (U 338-E) MOTION TO DISMISS COMPLAINT

BY THE ALLIANCE FOR NUCLEAR RESPONSIBILITY

� -��.��/� ��$��"��$��$�� "��"��0 �12�

� -��0 �"��"��0�� 3��1��4��5�6��778��$��$�

��!��"�� #$ ��%9!�#:)� ��-��(��"��6--�� 1��"��

��1��"��!��6��;�� 1�!�� %9!6�;!:)��-�"� ��<��0��$1��

�"��"� ��" ��$�� $� ��$��0 ��-��$��$�0��$��

��"��

�� 6��&��(��-��<��0 �"��"��

%9��:)��=�"��7��;��, �<��;��778��"��-��>�� $��3��

;��"��?��$�$�� %�"��9�� :)��$�� $��

�� "��!�#�"�$��$� �� $@�� 1��"��"��

Exhibit 1

Redline Showing Differences Between A4NR’s Original and Amended Complaints

BEFORE THEPUBLIC UTILITIES COMMISSIONOF THE STATE OF CALIFORNIAAlliance for Nuclear Responsibility, Complainantvs.CASE. ____________ _Southern California Edison Company (U238E), DefendantCOMPLAINTJOHN Ll. GEESMANDICKSON GEESMAN LLP1999 Harrison Street, Suite 2000Oakland, CA 94612Telephone: (510) 899-4670Facsimile: (510) 899-4671E-Mail: [email protected]: February 13, 2012Attorney forALLIANCE FOR NUCLEAR RESPONSIBILITYBEFORE THEPUBLIC UTILITIES COMMISSIONOF THE STATE OF CALIFORNIAAlliance for Nuclear Responsibility, Complainantvs.VS.CASE ____________ _Southern California Edison Company (U238E), DefendantCOMPLAINTI. Introduction.Pursuant to Cal. Pub. Util. Code § 2101 and Rule 4.1 of the California Public UtilitiesCommission (“Commission” or “CPUC” ) Rules of Practice and Procedure, the AllianceforNuclear Responsibility (“A4NR”) hereby files its complaint against Southern CaliforniaEdisonCompany (“SCE” ):• alleging multiple violations of California and federal securities laws by intentionally,recklessly, or negligently misrepresenting, by as much as $100 million, the amount ofCPUC-authorized inflation adjustment for the San Onofre Steam Generator ReplacementProject (“SGRP”) in written filings with the United States Securities and ExchangeCommission (“SEC”) and a conference call briefing to investment analysts by TheodoreF. Craver, Jr., chairman, president, and chief executive officer of Defendant SCE’sholding company, Edison International (“EIX”);• alleging multiple violations of the Commissiong g pg g p ’s Rule 1.1 by Defendant SCE in theyyundisclosed use of unauthorized inflation adjustments for the San Onofre SGRP in itsjjAdvice Letters 2355-E, 2521-E, 2648-E-A, and 2834-E;, , , ;, , , ;• alleging multiple violations of California and federal false claims statutes by DefendantSCE knowingly including such unauthorized inflation adjustments for the San OnofreSGRP in utility bills sent to Defendant SCE’s public sector customers, and certain of their

contractors and grantees;• alleging multiple violations of California’s “Unfair Competition Law” by DefendantSCE’sunlawful, unfair, or fraudulent practices regarding the inflation adjustments for the SanOnofre SGRP;• asking the Commission to: 1) consolidate adjudicationthe consideration of thiscomplaint with itsinvestigation of the San Onofre SGRP in I.12-10-013; 2) request1.12-10-013; 2) ; ); )determine whether there issufficient evidence to warrant the Commission exercising its authority under Cal. Pub.g yg yUtil. Code §§§§§§ 2101 or 2102 to bring suit in the name of the People of the State ofg pg pCalifornia; 3) determine whether there is sufficient evidence to warrant the; ); )Commission exercising its authorityg yg y under Cal. Pub. Util. Code § 2101 to request the aidqqof the Attorney General or the district attorney of the proper county or city and countyy p p yy yy yyy p p yy yy yyto institute court actions for the recovery of damagesand punishment of the violations of law alleged herein; and 3and prosecute appropriate actions or proceedings; 4p pp p p g ;p pp p p g ; ) issue anorder to showcause why Defendant SCE, EIX, and the individuals making the misrepresentationsalleged herein should not be found in contempt of the Commission under Cal. Pub. Util.Code § 2113.2113; and 5) provide such other relief as the Commission deems ; ) p; ) pappropriate.pp ppp pA4NR recognizes that the Commission may consider some of the misconduct allegedg y gyg y gyherein to be outside the ambit of its ability to remedy on its own, but is mindful that they yy ,yy yy ,yCalifornia Supreme Court has determined that the Commission may, and indeed p y,p y,sometimesmust, consider areas of law outside of its jurisdiction in fu lfilling its duties. Northern , j g, j gCaliforniaPower Agency v. Public Util. Com. {1971} 5 Co/3d 370 Moreover, application of the g y { } , ppyg y { } , ppyjudicialjjdoctrine of primary jurisdiction strongly argues for engagement of the Commissionp y j g yy g g gyp y j g yy g g gy ’s specialppexpertise in the factual matters underlying this complaint - and would likely stay a courtp y g p y yyp y g p y yy ’sdecisionmaking pending Commission resolution of those matters. Wise v. Pacific Gas & g p gg p gElectricCo. (1999) 77 Cal.App.4th 287( ) pp( ) ppII. Factual Allegations.1. Complainant A4NR is a 501c(3) corporation which represents both residential andsmallbusiness customers on nuclear energy issues before California and Federal regulatoryagencies,the Legislaturelegislaturegg , and Congress. A regular participant in CPUC nuclear-relatedproceedings, it iseligible to file this complaint pursuant to Rule 4.1.(a)(1) of the Commission’s Rules ofPracticeand Procedure. A4NR’s business address is P.O. Box 1328, San Luis Obispo, CA93406-1328. Its

telephone number is (858) 337-·2703.2. Defendant SCE is a public utility electrical corporation subject to the jurisdiction of theCommission. Its mailing address is 2244 Walnut Grove Avenue, Rosemead, CA 91770.Itstelephone number is (626) 302-3119.3. Complainant A4NR is a party in I.121.12-10-013 and its Data Request #7 in thatproceedingasked for copies of minutes of all meetings of the San Onofre Board of Review (((“(( BOR”) ))sinceJanuary 1, 2001 y ,yy ,y where the subject of replacement steam generators was discussed. TheSanOnofre Board of ReviewBOR is comprised of the several utility co-owners of the SanOnofre Nuclear GeneratingStation.4. In response to Complainant A4NR’s Data Request #7 in I.121.12-10-013, DefendantSCEprovided redacted minutes from the May 8, 2008, August 7,2008, November 14, 2008, , , g , , , ,, , g , , , ,Mayyy 2,2011, and July 28,, y ,y, y ,y 2011 meetingmeetingsg gg g , among others, of the San Onofre BOR.S. The unredacted portions of the minutes of the San Onofre BOR meetings identified inp gp gparagraph 4 above contain the only identifiable references to SGRP inflation adjustments p g p y jyp g p y jyorescalation factors in the post-January 1, 2001 time period covered by A4NRp y , p yyp y , p yy ’s Data Request #7qqin 1.12-10-013.6. The entire discussion of SGRP inflation adjustments or escalation factors reported in j pj ptheunredacted portions of the minutes of the San Onofre BOR meetings identified in p gp gparagraph 4p g pp g pabove is quoted in the italicized type of paragraphs 7, 9, 10, 12, and 13 below.q yp p g p , , , ,yq yp p g p , , , ,yBoard of Review. An7. The unredacted portion of the minutes of the May 2, 2011minutes reportedmeeting of the San OnofreggBOR reportspp the following exchange between Defendant SCE’s Senior Project Manager j gj gCraigggHarberts, Defendant SCE,, ’s Senior Vice President and Chief Nuclear Officer Peter T.Dietrich,,, andSan Diego Gas & Electric Senior Vice President James P. Avery:“Mr. Harberts then reviewed the SGRP budget status through March 2011. Mr. Averyg g yg g yasked that if the total SGRP costs were under $670M, would a reasonableness review be$ ,,required. Mr. Harberts responded that a reasonableness review would not be required inq p qq p qthat case. Mr. Avery asked what the cost of the project was in today’s dollars. Mr.Dietrich explained that if SCE used CPI as an escalation factor the project would be$25M over the $670M target,. but if SCE used the Handy-Whitman index,. the SGRPwould be $75M under the $670M target. Mr. Dietrich said that SCE asked for morespecificity from the CPUC on the escalation issue. Mr. Avery responded this was not hisrecollection,. SCE was insistent on being vague during the original filing.” II (emphasis( p( p

added)))A copy of the redacted May 2, 2011 minutes provided by Defendant SCE in response toComplainant A4NR’s Data Request #7 is attached to this complaint as Exhibit A.5.8. Complainant A4NR is informed and believes that Mr. Dietrich’s reference to “the$670million target” was to the SGRP’s complete cost, and not merely to Defendant SCE’s78.21%ownership share.9. Based on the un redacted portions of the minutes of the Sa n Onofre BOR, thep ,p ,significance of applying an inflation adjustment to g pp y g jg pp y g j “the $670 million target$ gg ” was recognized byg yg ySONGS co-owner SDG&E as early as mid-200B. The un redacted portion of the minutes y pyy pyof theMay B, 200B meeting of the San Onofre BOR reports the following briefing by y , g p g g yyy , g p g g yyDefendant SCE’sManager of SGRP Project Controls, David Opitz, and the response of SDG&Eg j , p , pg j , p , p ’s James P. Avery:yy“Dave provided an update on the Steam Generator Replacement Project contracts. Thep p p jp p p jtotal SGRP costs in 2004$ is $670.8M, with $400. 7M being contract costs and $270.1M$ $ , $ g $, gbeing other costs. The $400. 7M contract costs include $157 .2M in fixed price contracts,g $ $ p ,g p ,$2.5 in fixed price contracts with escalation, $1.0M in cost reimbursable contracts with$ p , $p ,no escalation, and $207.4M in cost reimbursable contracts with escalation. Future, $,allowance for contracts and subcontracts is $32.6M. The Bechtel Contract incorporated a$ pp$2.2M increase since the last Co-Owner update. Bechtel Change Order 7 includes: 2008$ p gp gescalation on non-manual labor, award of polar crane evaluation and polar crane, p p, p pinspection contracts, deletion of distribution transformer, and OLS runway pierp , , y pyp , , y pyevaluation. To offset the Bechtel Change Order and other trends offset by 2007 Edisong yg yunder runs, the contingency was reduced by $0.5M since the last Co-Owner update. This, g y yy $ py, g y yy pyconcluded Dave’s presentation.pp“Jim Avery requested a breakdown ofSGRP costs by both 2004$y q yy $yy q yy ’s and nominal byyycomponent with the escalation updated. Jim is concerned about the escalationp pp papproval hazard at the CPUC. Jim is requesting this tracking at all future BORpp q g gpp q g g ’s.”(emphasis added)( p )( p )A copy of the redacted May 8, 2008 minutes provided by Defendant SCE in response topy yy , p yy pypy yy , p yy pyComplainant A4NRpp ’s Data Request #7 is attached to this complaint as Exhibit B.q pq p10. The unredacted portion of the minutes of the August 7, 2008 meeting of the San p g , gp g , gOnofreBOR describes the following report from Defendant SCEg pg p ’s Mr. Opitz:pp“Dave gave an update on the CPUC Cost Estimate Variances. The application costg p ppg p ppestimate was $680 million in 2004$, $785 million in YOE$. The current cost estimate$ $, $ $,was $671 million in 2004$, $785 million in YOE$. This is based on actual escalation$ $, $ $,rates through 2006, updated 2007g , pg , p ·2011 projections to Handy-Whitman escalationp j yp j ytables trended as of 9/2007. with a reduction for deletion of HP Turbine Diaphragmp gp gwork. This_concluded Dave’s presentation on the SGRP Cost Performance Update.p pp p ”(emphasis added)( p )( p )

A copy of the redacted August 7, 2008 minutes provided by Defendant SCE in response py g , p yy pypy g , p yy pytoComplainant A4NRpp ’s Data Request #7 is attached to this complaint as Exhibit C.q pq p11. Complainant A4NR is informed and believes that pp “YOE$$” refers to year-of-expenditure-dollars.y py p12. The unredacted portion of the minutes of the November 14, 2008 meeting of the Sanp , gp , gOnofre BOR reflect co-owner SDG&E’s continued interest in the inflation adjustment jjtopic:pp“Jim Avery asked about escalation as SGRP was approved in $2004 dollars. Jim was toldy pp $yy ppythat Paul Hunt in Treasury group was working on a composite indeK of the appropriatey g p g p pp pyy g p g p pp pyescalation factors to apply to SGRP costs. SCE believes it will be able to support thepp y ppypp y ppyescalation factors used to apply to the SGRP costs.pp ypp y ” (emphasis added)( p )( p )A copy of the redacted November 14, 2008 minutes provided by Defendant SCE in py , p yypy , p yyresponse toppComplainant A4NRpp ’s Data Request #7 is attached to this complaint as Exhibit D.q pq p13. The unredacted portion of the minutes of the July 28, 2011 meeting of the San Onofrep y , gyp y , gyBOR reflect the regulatory significance of the $100 million difference embedded in the g y g $yg y gychoice ofinflation adjustment index:jj“Mr. Dietrich reminded the Board that the issue of escalation rates has not beenfinalized. In SCE’s filings with the California Public Utilities Commission (CPUC), g ( ),g ( ),Handyyy·yyyyWhitman escalation rates are always used to calculate escalation far longy gy g·gg term capitalppprojects. However, if the CPUC requires a different escalation methodology be used.p j , q gyp j , q gysuch as the Consumer Price Index, this would put the project into jeopardy of not, p p j j p y, p p j j p ycoming in at or under budget and a reasonableness review would be required if theg g qg g qbudget was exceeded by $100 million, but the impact of using a different escalationg y $ , p gyg y , p gymethodology wasngygy ’t expected to reach this threshold.pp ” (emphasis added)( p )( p )A copy of the redacted July 28, 2011 minutes provided by Defendant SCE in response topy yy , p yy pypy yy , p yy pyComplainant A4NRpp ’s Data Request #7 is attached to this complaint as Exhibit E.q pq p6.14. A transcript of the July 31, 2012, EIX second quarter earnings conference callconductedwith 11 investment analysts, quotes MrEIX CEO Theodore F. Craver, Jr.,, ,, , as saying thefollowing inhis opening remarks:“Turning to the regulatory review at the state level, there are several mechanisms inplace for the California Public Utilities Commission to provide oversight and review thereasonableness of expenditures related to the outage. First, the steam generator projectcost remains subject to a CPUC reasonableness review once SCE submits final cost fortheproject. As of June 30, SCE has spent $593 million on the project compared to theinflation-adjusted authorized spend of 0((($665 million, or SCE’s 78% ownershipshareshore.”(emphasis added)

This transcript is accessible at http://seekingalpha.com/article/767301-edison-internationalmanagement-international-managggement-discusses-q2-2012-results-earnings-call-transcript. Mr. Craver’s preparedremarks are available on the investor relations page of the EIX web site.7.IS. Mr. Craver’s quantification of a $66566S million “ authorized” inflation-adjustedamount forSCE’s ownership share of the SGRP was untrue. The CPUC’s 2005 decision had notauthorizedan inflation -adjusted amount and had specifically deferred that determination.Nevertheless,EIX had made a similar misrepresentation in its 10l0-K filing with the SEC datedFebruary 29, 2012which stated:“In 2005,2005. the CPUC authorized expenditures of approximately $525 million ($665million when adjusted for inflation) for SCE’s 78.21% share of San Onofre to purchaseand install new generators and remove their predecessors. Those expenditures remainsubject to CPUC review upon submission of SCE’s final costs for the overall project.SCEexpects to file an application with the CPUC setting forth final project costs in the thirdorfourth quarter of 2012.” (emphasis added)Exhibits 31.1 and 31.2 to the EIX 10l0-K, contained the respective certifications of Mr.Craver, asChief Executive Officer, and W. James Scilacci, as Chief Financial Officer, that“Based on my knowledge, this report does not contain any untrue statement of a0material fact or omit to state a material fact necessary tota make the statements made, inlight of the circumstances under which such statements were made, not misleading withrespect to the period covered by this report”Exhibit 32 to the EIX 10E1X l0-K contained the joint certification of Mr. Craver and Mr.Scilaccirequired by 18 U.S.C. § 1350, as enacted by § 906 of the Sarbanes-Oxley Act of 2002.The EIX10l0-K and its exhibits are available on the investor relations page of the EIX web site.8.16. The SCE 10-K filing with the SEC dated February 29, 2012 contained the identicaldescription of the authorized SGRP expenditures as the EIX 10l0-K of the same date, aswell ascertifications identical to those of Mr. Craver and Mr. Scilacci from SCE PresidentRonald L.Litzinger and SCE Chief Financial Officer Linda G. Sullivan. The SCE 10-K and itsexhibits areavailable on the investor relations page of the EIX web site.9.17. The 10l0-Q reports EIX and SCE filed separately with the SEC dated May 2, 20122,2012,, ; July 31,2012; and November 1, 2012 each described the $665 million “authorized” inflation-adjustedamount for SCE’s ownership share of the SGRP in the same way:

“In 2005,2005. the CPUC authorized expenditures of approximately $525 million ($665million when adjusted for inflation) for SCE’s 78.21% share of San Onofre to purchaseand install the four new steam generators in Units 2 and 3 and remove and dispose oftheir predecessors.” (emphasis added)The requisite certifications for each EIX filing were made by Mr. Craver and Mr.Scilacci, and foreach SCE filing by Mr. Litzinger and Ms. Sullivan. Each of the 10-K reports and itsexhibits areavailable on the investor relations page of the EIX web site.10. The broad authority conferred upon the Commission by18.yy Cal. Pub. Util. Code §816, et seq. confers broad authority on the Commission yy to exercisethe power of supervision, regulation, restriction, and control of the issuance of securitiesbypublic utilities. Continued access to the capital markets by public utilities regulated by thep y p g yyp y p g yyCommission requires faithful adherence to California and federal securities laws. Thein order to enable such utilities continued access to the capital markets. The Commissionhas a particularly strong interest in assuring Defendant SCE’s compliance.,,,especially in matters relating to the representations about Commission decisions.p y g pyp y g py11.19. Contrary to Mr. Craver’s statement in the July 31, 2012 quarterly earnings call, andcontrary to the similar representations by EIX and SCE in eight separate 10-K or 10-Qfilings withthe SEC, the CPUC actually went to considerable length in its 2005 decision approvingthe SGRP,D.05-12-040, to emphasize that it was not authorizing a particular adjustment forinflation atthat time. As discussed in D.05-12-040’s Ordering Paragraphs:“13. The selection of the appropriate inflation adjustment to convert the 2004 dollarsadopted herein to nominal dollars will be addressed in SCE’s application to includeSGRPcosts permanently in rates.”***“15. The selection of the appropriate inflation adjustment to convert future O&M costsand capitalcapitolpp additions as shown in Attachment A from 2004 dollars to theappropriatefuture year dollars shall be determined in the proceedings specified in OrderingParagraph 12.”1

20. Although superficially of two minds about the type of Commission proceeding inwhichthe appropriate inflation adjustment should eventually be selected, the Conclusions ofLawlaw in D.050.05-12-040 conclusively yy established that such selection had not yet been made:“46. The selection of the appropriate inflation adjustment applicable to recorded SGRPcosts should be addressed in SCE’s application to include SGRP costs permanently in

1 Complainant A4NR believes this to be a typographical error, since Ordering Paragraph 12 discusses depreciation rather than proceedings, and believes the intended reference is to Ordering Paragraph 13.

rates.” “***“68. Since the inflation adjustment was not addressed in the record, the selection of theappropriate inflation adjustment applicable to the costs shown in Attachment A shouldbe considered in proceedings such as GRCs where revenue requirements and rates areset.” H21. The Findings of Fact in D0 .05-12-040 provided additional insight into theCommission’sthinking. The only example cited in the entire decision of a specific index that might beused forfuture inflation adjustments was the Consumer Price Index – -which, as described inParagraph 47above, by May 2,March,,, 2011 had produced an authorized cost level $100 million belowthe amountcalculated by Defendant SCE using the Handy Whitman Index:“146.N145,,, In this decision, costs are expressed in 2004 dollars.“H147. Actual costs will be expressed in nominal dollars when they are recorded.“148. A meaningful comparison of recorded SGRP costs with the costs specified hereinwill require all costs to be converted to equivalent year dollars by an inflationadjustment.“149. The inflation adjustment should be made based on reliable publications such asthe Consumer Price Index published by the U.S. Bureau of Labor Statistics.“150. The record is not sufficient to address how the inflation adjustment should bemade.” “12.22. Defendant SCE filed its Advice Letterletter 2521-·E with the CommissionNovember 1, 2010 torecover $56.694 million in 2011 for completion of the installation of the Unit 2replacementsteam generators. According to SCE Advice Letterletter 2521-·E, the requested amount“includes estimated depreciation, property taxes, income taxes, return on rate base, andFranchise Fees and Uncollectibles consistent with Preliminary Statement, Part Z.”The reference to Preliminary Statement, Part Z related to the SONGS 2&3 SteamGeneratorReplacement Balancing Account approved earlier by the Commission’s Energy DivisionDirectorpursuant to SCE Advice Letterletter 2355-·E. Neither SCE Advice Letterletter 2521-E,nor PreliminaryStatement, Part Z, made any mention of an inflation adjustment. SCE Advice Letterletter2521-·E wasapproved by the Commission’s Energy Division Director December 7, 2010.13.23. Defendant SCE filed its Advice Letterletter 2648-E-A with the Commission onDecember 27,2011 to recover $57.540 million in 2012 for completion of the installation of the Unit 3replacement steam generators, as well as $57.699 million in 2012 for the Unit 2replacement

steam generators. No explanation for the $1.005 million increase from 2011 to 2012 inthe Unit2 amount was offered. According to SCE Advice Letterletter 2648-E-A,“The total 2012 forecast SONGS 2&3 steam generators revenue requirement isestimated to be $115.239 million and includes estimated depreciation, taxes, return onrate base, plus FF&U, consistent with Preliminary Statement, Part Z.”The reference to Preliminary Statement, Part Z related to the SONGS 2&3 SteamGeneratorReplacement Balancing Account approved earlier by the Commission’s Energy DivisionDirectorpursuant to SCE Advice Letterletter 2355-· E. Neither SCE Advice Letterletter 2648-E-A,nor PreliminaryStatement, Part Z, made any mention of an inflation adjustment. SCE Advice Letterletter2648-E-Awas approved by the Commission’s Energy Division Director June 13, 2012.14.24. Pursuant to the approval by the Commission’s Energy Division Director of SCEAdviceLetterletter 2521-·E and SCE Advice Letterletter 2648-E-A, Defendant SCE includedcumulative revenuerequirements of $171,933,000 in its rates and charges for 2011 and 2012 for its share oftheSGRP costs recorded in Preliminary Statement, Part Z, without disclosing what inflationadjustment, ifjfjj any, was used in determining these revenue requirements.15.25. Defendant SCE filed its Advice Letterletter 2834-·E on December 31, 201231,2012,, to recover $ 112.843million in 2013 for replacement of the Unit 2 and Unit 3 steam generators, but the requestremains pending. SCE Advice Letter 2834-E makes no mention of whether an inflationadjustment was used to calculate the amount requested, which“includes estimated depreciation, taxes, return on rate base, plus FF&U, consistent withD.05-·12-040 and Preliminary Statement Part Z.”16.26. Defendant SCE knows that the Commission has not yet authorized a particularinflationadjustment for Defendant SCE’s share of SGRP costs recorded in Preliminary Statement,Part Z.27. Complainant A4NR is informed and believes that Defendant SCE used an inflationppadjustment for the SGRP costs addressed in Defendant SCEjj ’s Advice Letters 2355-E, ,,2521-E,,,2648-E-A, and 2834-E.,,17.28. Complainant A4NR is informed and believes that Defendant SCE used an inflationadjustment, most likely the Handy Whitman Index or a composite of different indexes, tocalculate the portion of its share of SGRP costs to include in its 2011, 2012 and proposed2013rates and charges.III. Causes of Action.FIRST CAUSE OF ACTIONViolation of Cal. Corp. Code § 254002S400(d)

Incorporating by reference paragraphs 1 through 1728 herein, Complainant A4NR allegesthe following:18.29. On multiple occasions, Defendant SCE intentionally, recklessly, or negligentlymadeuntrue statements of material facts regarding the Commission’s authorization of a specificinflation adjustment for Defendant SCE’s share of the cost of the SGRP. These occasionsinclude but are not limited to:;;;a) the February 29, 2012 filing of SCE’s 10-K with the SEC;b) the February 29, 2012 filing of EIX’s 10-K with the SEC;c) the May 2, 2012 filing of SCE’s 10-Q0 with the SEC;d) the May 2, 2012 filing of EIX’s 10-Q0 with the SEC;e) the July 31, 2012 filing of SCE’s 10-Q0 with the SEC;f) the July 31, 2012 filing of EIX’s 10-Q with the SEC;g) the July 31, 201231,2012,, conference call with investment analysts;h) the November 1, 2012 filing of SCE’s 10-Q0 with the SEC;i) the November 1, 2012 filing of SCE’s 10-Q·0 with the SEC.19.30. On multiple occasions, Defendant SCE intentionally, recklessly, or negligentlyomitted tostate material facts, regarding the Commission’s D.05-12-040 treatment of SGRP costinflationadjustment, necessary to make the statements Defendant SCE did make, in light of thecircumstances under which they were made, not misleading. These occasions include butarenot limited to:a) the February 29, 2012 filing of SCE’s 10-K with the SEC;b) the February 29, 2012 filing of EIX’s 10-K with the SEC;c) the May 2, 2012 filing of SCE’s 10l0-Q with the SEC;d) the May 2, 2012 filing of EIX’s 10-Q with the SEC;e) the July 31, 2012 filing of SCE’s 10-Q0 with the SEC;f) the July 31, 2012 filing of EIX’s 10-Q with the SEC;g) the July 31, 2012 conference call with investment analysts;h) the November 1, 2012 filing of SCE’s 10-Q with the SEC;i) the November 1, 2012 filing of SCE’s 10-Q with the SEC.20.31. The certifications described in paragraphs 715 through 917 above were eachknowingly orwillfully made with regard to Commission authorization of a specific inflation adjustmentforDefendant SCE’s share of the cost of the SGRP21.32. Defendant SCE’s conduct violated Cal. Corp. Code § 25400(2S400{( {( {d).SECOND CAUSE OF ACTIONViolation of 15 U.S.C. § 77q(a) and 15 U.S.C. § 78j(b)Incorporating by reference paragraphs 1 through 2132 herein, Complainant A4NR allegesthe following:22.33. Defendant SCE’s conduct alleged in paragraphs 1829 through 21 herein31 aboveviolated Section

17(a) of the federal Securities Act of 1933, codified as 15 U.S.C. § 77q(a), and Section10l0(b) ofthe federal Exchange Act of 1934, codified as 15 U.S.C. § 78j(b) and is subject topotentialenforcement action by the SEC.THIRD CAUSE OF ACTIONViolation of Cal. Gov. Code § 12650, et seq.20 CCR §§§ 1.1Incorporating by reference paragraphs 1 through 33 herein, Complainant A4NR allegesp g y p g p g , p gyp g y p g p g , p gythe following:gg34. Defendant SCE’s use of an inflation adjustment for the SGRP costs addressed by itsj yj yAdvice Letters 2355-E, 2521-E, 2648-E-A, and 2834-E was an artifice or false statement , , ,, , ,of factor law which misled or attempted to mislead the Commission or its staff and violated ppRule1.1 ofthe CPUC Rules of Practice and Procedure.35. Defendant SCE’s failure to disclose its use of an inflation adjustment for the SGRP jjcostsaddressed by its Advice Letters 2355-E, 2521-E, 2648-E-A, and 2834-E was an artifice or y , , ,y , , ,falsestatement of fact or law which misled or attempted to mislead the Commission or its staff ppandviolated Rule 1.1 of the CPUC Rules of Practice and Procedure.36. Pursuant to Cal. Pub. Util. Code §§§ 2108, each violation of Rule 1.1 by Defendant , y, ySCE’sAdvice Letters 2355-E, 2521-E, 2648-E-A, and 2834-E is a continuing violation, and , , , g ,, , , g ,each dayyy’yyyy scontinuance thereof is a separate and distinct offense.ppFOURTH CAUSE OF ACTIONViolation of Cal. Gov, Code ,, §§§ 12650, et seq., q, qIncorporating by reference paragraphs 1 through 2236 herein, Complainant A4NR allegesthe following:23.37. To the extent Defendant SCE’s 2011 and 2012 rates and charges included anyinflationadjustment for its share of SGRP costs recorded in Preliminary Statement, Part Z, suchinflationadjustment was knowingly included by Defendant SCE.24.38. To the extent that Defendant SCE’s 2011 and 2012 rates and charges included anyinflation adjustment for its share of SGRP costs recorded in Preliminary Statement, PartZ, andwere submitted in Defendant SCE’s billings to California state agencies or politicalsubdivisions,they violated the California False Claims Act, Cal. Gov. Code § 12650, et seq. DefendantSCEknowingly made, used, or caused to be made or used, false records or statements to getfalse

claims paid or approved by California state agencies or political subdivisions andknowinglymade, used, or caused to be made or used, false records or statements material to false orfraudulent claims.25.39. Defendant SCE is liable for a claim of treble damages to such California stateagenciesand political subdivisions, as well as for penalties and costs, in a specific amount to bedetermined at trial in court.26.40. The information upon which this complaint is based is in the public domain, andA4NR isnot seeking to be a qui tam plaintiff or relator under Cal. Gov. Code § 12650, et seq.FOURTHFIFTH CAUSE OF ACTIONViolation of 31 U.S.C. § 3279, et seq.Incorporating by reference paragraphs 1 through 2640 herein, Complainant A4NR allegesthe following:27.41. To the extent that Defendant SCE’s 2011 and 2012 rates and charges included anyinflation adjustment for its share of SGRP costs recorded in Preliminary Statement, PartZ, andwere submitted in Defendant SCE’s billings to an officer, employee, or agent of theUnited States federal government (the “Federal Government”); or submitted to acontractor orgrantee of the Federal Government using funds provided by the Federal Government orreimbursable by the Federal Government to advance a Federal Government program orinterest, and such funds were used to pay Defendant SCE’s billings; Defendant SCE’sbillingsviolated the federal False Claims Act, 31 U.S.C. § 3279, et seq. Defendant SCEknowingly made,used, or caused to be made or used, false records or statements to get false claims paid orapproved by the Federal Government or its contractors or grantees and knowingly made,used,or caused to be made or used, false records or statements material to false or fraudulentclaims.28.42. Defendant SCE is liable for a claim of treble damages to the Federal Government,and tocertain of its contractors and grantees, as well as for penalties and costs, in a specificamount tobe determined at trial in court.29.43. The information upon which this complaint is based is in the public domain, andA4NR isnot seeking to be a qui tam plaintiff or relator under 31 U.S.C. § 3279, et seq.FIFTHSIXTH CAUSE OF ACTIONViolation of Cal. Bus. & Prof. Code § 17200, et seq.Incorporating by reference paragraphs 1 through 2943 herein, Complainant A4NR allegesthe following:30.44. Defendant SCE has engaged in, and continues to engage in, unlawful, fraudulent,or

unfair acts or practices in the conduct of a business, which acts or practices constituteunfaircompetition, as that term is defined in Cal. Bus. & Prof. Code § 17200. Such acts orpracticesinclude, but are not limited to, the following:a) violating Cal. Corp. Code § 25400(d) as described in the First Cause of Actionabove;b) violating 15 U.S.C. § 77q(a) and 15 U.S.C. § 78j(b) as described in the SecondCause of Action above;c) violating 20 CCR gg §§§ 1.1 as described in the Third Cause of Action above;;;d) violating) g) g Cal. Gov. Code § 12650, et seq., as described in the ThirdFourth Cause ofAction above; andde) violating 31 U.S.C. § 3279, et seq., as described in the FourthFifth Cause of Actionabove.31.45. Defendant SCE is liable for restitution, costs and civil penalties in a specificamount tobe determined at trial in court.IV. Prayer for ReliefWHEREFORE, Complainant A4NR respectfully asks the Commission to(1) consolidate adjudicationthe consideration of this complaint, pursuant to Rule 7.4 oftheCommission’s Rules of Practice and Procedure, with its investigation of the San OnofreSGRP in I.121.12-10-013;(2) requestdetermine whether there is sufficient evidence to warrant the Commissionexercising its authority under Cal. Pub. Util. Code g yg y §§§§§§ 2101 or 2102 to bring suit in theggname of the People of the State of California;p ;p ;(3) determine whether there is sufficient evidence to warrant the Commission( )( )exercising its authorityg yg y under Cal. Pub. Util. Code § 2101 to request qq the aid of theAttorney General’s assistanceto institute court actions for the recovery of damages and punishment of the violations or the district attorney of the proper county or city and y p p yy yyy p p yy yycounty toyyof law alleged herein;institute and prosecute appropriate actions or proceedings;p pp p p g ;p pp p p g ;(34) issue an order to show cause why SCE, EIX, and the individuals making themisrepresentations alleged herein should not be found in contempt of the Commissionunder Cal. Pub. Util. Code § 2113; and(45) provide such other relief as the Commission deems appropriate.V. Contact Information.All pleadings, correspondence, and other communications concerning this complaintshould be directed to Complainant A4NR’s attorney as follows:John L. GeesmanDICKSON GEESMAN LLP1999 Harrison Street, Suite 2000Oakland, CA 94612Telephone: (510) 899-4670Facsimile: (510) 899-4671E-Mail: [email protected] @ g john@dicksongeesma n.comj @ gjj @ g

VI. Scoping Information and Proposed Schedule.Complainant A4NR requestsreque stsqq that this matter be categorized as an adjudicatoryproceeding and expects the need for any evidentiary hearing to be determined by thecontentof Defendant SCE’s answer. If Defendant SCE proffers evidence that it did not includeanyinflation adjustment in calculating its billings, or that it had express Commissionauthorizationfor the inflation adjustment which it used, the need for hearing is conceivable and can beaccommodated within the currently scheduled Phase 1 hearings in I.121.12-10-013.Otherwise,what is at issue are questions of law rather than questions of fact, and thesethat can beresolved through briefing in Phase 1 of I.121.12-10-013, well within the 12 months allowed for adjudicatory proceedings by Rule 4.2(a) oftheCommission’s Rules of Practice and Procedure. The specific issues to be decided arewhetherthere is sufficient evidence that Defendant SCE’s conduct constituted violations of law,asalleged in the complaint’s fivesix causes of action, which merit the Commission requesting theAttorney General to initiateto warrant the initiation of court proceedingsand/or findings by the Commission of contempt regarding Defendant SCE, EIX, Mr. Craver, Mr. Scilacci, Mr. Litzinger, and Ms. Sullivanand theindividuals making the misrepresentations alleged hereing p gg p g .Respectfully submitted,By: /s/ John L. GeesmanJOHN Ll. GEESMANDICKSON GEESMAN LLPDate: February 13,18,,, 2013Attorney forALLIANCE FOR NUCLEAR RESPONSIBILITYVERIFICATIONI, John L. Geesman, declare under penalty of perjury:I am an attorney licensed to practice before the courts of the State of California. Irepresentcomplainant, Alliance for Nuclear Responsibility (“A4NR”), in this matter before theCaliforniaPublic Utilities Commission. A4NR is absent from the county in which my office islocated, andtherefore I verify this document on their behalf.I have read the foregoing Complaint and know the contents thereof, and declare thecontentsof the document are true to my own knowledge, except for those matters that are stated oninformation or belief, and as to those matters IJ believe them to be true.Executed this 1318th day of February, 2013, at Oakland, California./s/ Johnjohnjj L. GeesmanJOHN L. GEESMAN

Document comparison by Workshare Compare on Tuesday, March 05, 201312:11:42 PMInput:

Document 1 ID file://C:\Users\thomdl\Desktop\Miyake\20030253_1.docDescription 20030253_1Document 2 ID file://C:\Users\thomdl\Desktop\Miyake\20900967_1.docDescription 20900967_1Rendering set MTO 1 (email)

Legend:

Insertion Deletion Moved from Moved to Style changeFormat changeMoved deletion Inserted cellDeleted cellMoved cellSplit/Merged cellPadding cell

Statistics:

CountInsertions 281Deletions 154Moved from 0Moved to 0Style change 0Format changed 0Total changes 435

CERTIFICATE OF SERVICE

I hereby certify that, pursuant to the Commission’s Rules of Practice and Procedure, I

have this day served a true copy of SOUTHERN CALIFORNIA EDISON COMPANY’S

(U 338-E) MOTION TO DISMISS COMPLAINT BY THE ALLIANCE FOR NUCLEAR

RESPONSIBILITY on all parties identified on the attached service list(s) C.13-02-013. Service

was effected by one or more means indicated below:

☒ Transmitting copies to the CPUC Docket Office via overnight delivery.

☒ Placing the copies in sealed envelopes and causing such envelopes to be

delivered by hand or by overnight courier to the offices of the Commissioner(s) or other addressee(s).

ALJ Melanie Darling CPUC, Div of ALJ's 505 Van Ness Ave, Room 5115 San Francisco, CA 94102

Commissioner Michel P. Florio 505 Van Ness Ave. San Francisco, CA 94102

Executed this April 10, 2013, at Rosemead, California.

_/s/ Raquel Ippoliti_________________________ Raquel Ippoliti Project Analyst SOUTHERN CALIFORNIA EDISON COMPANY

2244 Walnut Grove Avenue Post Office Box 800 Rosemead, California 91770

PROCEEDING: C1302013 - ALLIANCE FOR NUCLEAR FILER: ALLIANCE FOR NUCLEAR RESPONSIBILITY LIST NAME: LIST LAST CHANGED: MARCH 27, 2013

DOWNLOAD THE COMMA-DELIMITED FILE ABOUT COMMA-DELIMITED FILES

Back to Service Lists Index

JANET S. COMBS, ESQ. JOHN L. GEESMAN SR. ATTORNEY ATTORNEY SOUTHERN CALIFORNIA EDISON COMPANY DICKSON GEESMAN LLP 2244 WALNUT GROVE AVE., PO BOX 800 1999 HARRISON STREET, STE. 2000 ROSEMEAD, CA 91770-3714 OAKLAND, CA 94612 FOR: SOUTHERN CALIFORNIA EDISON COMPANY FOR: ALLIANCE FOR NUCLEAR RESPONSIBILITY (A4NR)

CASE ADMINISTRATION HENRY WEISSMAN SOUTHERN CALIFORNIA EDISON COMPANY SOUTHERN CALIFORNIA EDISON 2244 WALNUT GROVE AVENUE / PO BOX 800 2244 WALNUT GROVE AVE. ROSEMEAD, CA 91770 ROSEMEAD, CA 91770 RUSSELL A. ARCHER RUSSELL G. WORDEN ATTORNEY DIRECTOR SOUTHERN CALIFORNIA EDISON COMPANY SOUTHERN CALIFORNIA EDISON COMPANY 2244 WALNUT GROVE AVE. / PO BOX 800 2244 WALNUT GROVE AVENUE ROSEMEAD, CA 91770 ROSEMEAD, CA 91770 WALKER A. MATTHEWS III CALIFORNIA ENERGY MARKETS SENIOR ATTORNEY 425 DIVISADERO STREET, SUITE 303 SOUTHERN CALIFORNIA EDISON COMPANY SAN FRANCISCO, CA 94117

CPUC Home

CALIFORNIA PUBLIC UTILITIES COMMISSION Service Lists

Parties

Information Only

Page 1 of 2CPUC - Service Lists - C1302013

4/10/2013http://www.cpuc.ca.gov/service_lists/C1302013_80756.htm

2244 WALNUT GROVE AVENUE, ROOM 390 ROSEMEAD, CA 91770

MELANIE DARLING CALIF PUBLIC UTILITIES COMMISSION DIVISION OF ADMINISTRATIVE LAW JUDGES ROOM 5041 505 VAN NESS AVENUE SAN FRANCISCO, CA 94102-3214

TOP OF PAGE BACK TO INDEX OF SERVICE LISTS

State Service

Page 2 of 2CPUC - Service Lists - C1302013

4/10/2013http://www.cpuc.ca.gov/service_lists/C1302013_80756.htm