United States v. Southern California Edison Co. (413 F. Supp. 2d 1101, 2006)

Citations

413 F. Supp. 2d 1101

Full opinion text

MEMORANDUM AND ORDER DENYING PLAINTIFF’S CROSS MOTIONS FOR PARTIAL SUMMARY JUDGMENT (DOCS. 257) AND DENYING DEFENDANT’S CROSS MOTIONS FOR SUMMARY JUDGMENT (DOCS. 253).

WANGER, District Judge.

I. INTRODUCTION

This is an action for damages stemming from a fire allegedly ignited by electrical equipment operated by Defendant Southern California Edison Company (“Defendant” or “SCE”) in Big Creek, California. The fire caused damage to property belonging to the United States of America (“Plaintiff’). Plaintiff alleges that the fire ignited when a squirrel came into contact with a 12kV transformer located within an enclosure known as the 12kV substation.

The parties cross-move for partial summary judgment on the issue of whether the 12kV substation is covered by the Federal Energy Regulatory Commission (“FERC”) licenses held by SCE. Even if the 12kV substation is not covered by the terms of the FERC licenses, the government moves in the alternative for partial summary judgment on the issue of whether SCE is nonetheless liable under the terms of the licenses. Finally, if SCE is found not to be liable under the terms of the license, the government moves for partial summary judgment that SCE is liable in trespass regardless of fault.

The parties have each filed lengthy statements of undisputed fact and eviden-tiary objections thereto. (See Docs. 275, 284 Attch. 1; 289; 291; 294; 297.)

II. GENERAL BACKGROUND AND PROCEDURAL HISTORY

SCE operates a hydroelectric power generation facility in Big Creek, California, which is located on federal lands, inside the boundary of the Sierra National Forest. On August 24, 1994, a fire ignited in the vicinity of Big Creek Powerhouses Nos. 2 and 2A. (SCE Undisputed Fact (“SCE UF”) # 1, Doc. 298; Plaintiffs Undisputed Fact (“USA UF”) # 1, Doc. 297.) The fire (“Big Creek fire”) allegedly burned more than 5,000 acres of National Forest lands before it was extinguished. (Second Amended Complaint (“Complaint”), ¶ 6.) The fire apparently began when a squirrel came into contact with one of the 7.2/12kV transformers located in a switchyard (the “12kV substation”) near Powerhouses Nos. 2 and 2A. (SCE UF # 3; USA UF # 3.)

Both Powerhouse Nos. 2 and 2A are owned and operated by Defendant under licenses from the Federal Energy Regulatory Commission (“FERC”). (USA UF # 8 & # 14.) The 12kV substation is a fenced-in yard located approximately 400 feet from Powerhouses Nos. 2 and 2A and contains various pieces of equipment, including several 12kV transformers. (See SCE UF #8.) The 12kV transformers located within the 12KV substation step up a 7,000 volt (“7kV”) power source from Big Creek Powerhouse No. 2 to 12,000 volts (“12kV”). (SCE UF # 10.)

The Complaint contains fifteen causes of action: (1) breach of the Project No. 2175 license, (2) indemnity under the Project 2175 license, (3) breach of Project No. 67 license, (4) indemnity under the Project 67 license, (5) breach of Memorandum of Understanding, (6) breach of Special Use Permit, (7) trespass to federal lands, (8) trespass in violation of California Civil Code § 3346, (9) trespass by fire, (10) Trespass under California Civil Code § 3334, (11) negligence per se for violation of Cal. Pub. Res.Code § 4291, (12) liability under Cal. Health and Safety Code §§ 13007 and 13008, (13) negligence based on Pub. Util. Code § 451, (14) negligence, (15) recovery of interest, penalties, and investigative, administrative and collection costs. (Doc. 172, filed Nov. 30, 2004.)

During the early stages of discovery, SCE responded to requests for admissions, admitting that the Project 2175 and 67 Licenses applied to the Transformer and 12kV substation. (See Doc. 126, filed Sept. 21, 2004.) After reviewing documents produced by the government in discovery, SCE moved to withdraw these admissions. On October 22, 2004, the magistrate judge granted SCE’s motion to withdraw admissions. (Doc. 150, filed Oct. 22, 2004.) The United States was given leave to amend its complaint and submit a plan for additional discovery. (Doc. 150 at 8-9.) During the hearing on the motion to withdraw, the magistrate judge suggested that the scheduling order in this case be amended to allow additional time for discovery. The parties then moved to modify the scheduling order. (Docs. 157, filed Oct. 27, 2004, and 158, filed Oct. 28, 2004.)

With the original summary judgment motion approaching (and the scheduling order not yet modified by the court), the parties filed motions for partial summary judgment. (Doc. 139, filed Oct. 15, 2004; Doc. 159, filed Oct. 29, 2004; Doc. 176, filed Nov. 30, 2004.) At the hearing on those motions, the parties agreed to postpone summary judgment proceedings to provide both sides additional time for discovery for all but one discrete legal issue: Whether the United States is entitled to assert a claim for prejudgment interest on any recovery under the FERC licenses. The district court granted summary judgment for the government on this issue, finding that such a claim may be pursued. (See Doc. 205, filed Jan. 25, 2005.)

Following the hearing on the first round of summary judgment motions, a new scheduling order was entered. (Doc. 211, filed Feb. 6, 2005.) Among other deadlines, the revised scheduling order set April 5, 2005 as the deadline for “further disclosure of experts” and May 5, 2005 as the deadline for “supplemental expert disclosure.” (Id. at 2.) The district court also stated that “either side may disclose any further experts by April 5th, and any rebuttal or supplemental experts to the new experts by May 5th.” On April 5, 2005, Edison designated Joel Prehiem and Geoffrey Rabone, both Edison employees, as expert witnesses. The United States disclosed no expert on this date. On May 5, 2005, the United States designated Kevin J. Mara and Cynthia A. Whelan as experts. The United States later withdrew Ms. Whelan as an expert. Mr. Mara’s expert report was provided to SCE along with the May 5, 2005 disclosure. On May 23, 2005, Edison moved to strike Mr. Mara’s opinion. (Doc. 230.)

In a decision filed July 13, 2005, the magistrate judge found that the district court “did not intend to limit the May 5th designation to supplementation to an initial disclosure or rebuttal to other experts designated.” (Doc. 250 at 5.) In the alternative, even if the modified scheduling order only permitted the designation of rebuttal witnesses on May 5, 2005, the magistrate judge’s July 12, 2005 order found that Mr. Mara’s opinion was proper rebuttal testimony. (Id.)

SCE requested reconsideration of the magistrate judge’s order. (Doc. 260, filed July 27, 2005.) The district court, interpreting the language of its own order, found that Mr. Mara’s opinion was not proper rebuttal testimony and struck his expert opinions. (Doc. 272, filed Sept. 23, 2005.)

III. STANDARD OF REVIEW

Summary judgment is warranted only “if the pleadings, depositions, answers to interrogatories, and admissions on file, together with the affidavits, if any, show that there is no genuine issue as to any material fact.” Fed.R.Civ.P. 56(c); California v. Campbell, 138 F.3d 772, 780 (9th Cir.1998). Therefore, to defeat a motion for summary judgment, the non-moving party must show (1) that a genuine factual issue exists and (2) that this factual issue is material. Id. A genuine issue of fact exists when the non-moving party produces evidence on which a reasonable trier of fact could find in its favor viewing the record as a whole in light of the evidentiary burden the law places on that party. See Triton Energy Corp. v. Square D Co., 68 F.3d 1216, 1221 (9th Cir.1995); see also Anderson v. Liberty Lobby, Inc., 477 U.S. 242, 252-56, 106 S.Ct. 2505, 91 L.Ed.2d 202 (1986). The evidence must be viewed in a light most favorable to the nonmoving party. Indiana Lumbermens Mut. Ins. Co. v. West Oregon Wood Products, Inc., 268 F.3d 639, 644 (9th Cir.2001). Facts are “material” if they “might affect the outcome of the suit under the governing law.” Campbell, 138 F.3d at 782 (quoting Liberty Lobby, Inc., 477 U.S. at 248, 106 S.Ct. 2505).

The moving party bears the initial burden of demonstrating the absence of a genuine issue of fact. Devereaux v. Abbey, 263 F.3d 1070, 1076 (9th Cir.2001). If the moving party fails to meet this burden, “the nonmoving party has no obligation to produce anything, even if the nonmoving party would have the ultimate burden of persuasion at trial.” Nissan Fire & Marine Ins. Co., Ltd. v. Fritz Cos., Inc., 210 F.3d 1099, 1102-03 (9th Cir.2000). However, if the nonmoving party has the burden of proof at trial, the moving party must only show “that there is an absence of evidence to support the nonmoving party’s case.” Celotex Corp. v. Catrett, 477 U.S. 317, 325, 106 S.Ct. 2548, 91 L.Ed.2d 265 (1986). Once the moving party has met its burden of proof, the non-moving party must produce evidence on which a reasonable trier of fact could find in its favor viewing the record as a whole in light of the evidentiary burden the law places on that party. Triton Energy Corp., 68 F.3d at 1221. The nonmoving party cannot simply rest on its allegations without any significant probative evidence tending to support the complaint. Devereaux, 263 F.3d at 1076.

[T]he plain language of Rule 56(c) mandates the entry of summary judgment, after adequate time for discovery and upon motion, against a party who fails to make a showing sufficient to establish the existence of an element essential to the party’s case, and on which that party will bear the burden of proof at trial. In such a situation, there can be “no genuine issue as to any material fact,” since a complete failure of proof concerning an essential element of the nonmoving party’s case necessarily renders all other facts immaterial.

Celotex Corp., 477 U.S. at 322-23, 106 S.Ct. 2548.

“In order to show that a genuine issue of material fact exists, the nonmoving party must introduce some ‘significant probative evidence tending to support the complaint.’ ” Rivera v. National Railroad Passenger Corporation, 331 F.3d 1074, 1078 (9th Cir.2003) (quoting Liberty Lobby, Inc., 477 U.S. at 249, 106 S.Ct. 2505). If the moving party can meet his burden of production, the non-moving party “must produce evidence in response.... [H]e cannot defeat summary judgment with allegations in the complaint, or with unsupported conjecture or conclusory statements.” Hernandez v. Spacelabs Med., Inc., 343 F.3d 1107, 1112 (9th Cir.2003). “Conclusory allegations unsupported by factual data cannot defeat summary judgment.” Rivera, 331 F.3d at 1078.

The more implausible the claim or defense asserted by the nonmoving party, the more persuasive its evidence must be to avoid summary judgment. See United States ex rel. Anderson v. N. Telecom, Inc., 52 F.3d 810, 815 (9th Cir.1995). Nevertheless, “[t]he evidence of the non-mov-ant is to be believed, and all justifiable inferences are to be drawn in its favor.” Liberty Lobby, Inc., 477 U.S. at 255, 106 S.Ct. 2505. A court’s role on summary judgment is not to weigh evidence or resolve issues; rather, it is to find genuine factual issues. See Abdul-Jabbar v. G.M. Corp., 85 F.3d 407, 410 (9th Cir.1996).

IV. SUMMARY OF THE PARTIES’ MOTIONS

Several of the United States’ claims for relief allege that SCE breached certain terms and conditions of the FERC licenses covering Project 67 and Project 2175. The United States asserts that SCE operates Big Creek Powerhouses No. 2 and 2A and associated works, including the 12kV substation and the transformers that allegedly sparked the fire, under these licenses. The licenses contain indemnification language that, according to the United States, would require SCE to pay for damage to the property of the United States caused by facilities covered by the licenses. SCE denies that the licenses apply to the 12kV substation and/or the 12kV transformers and that, therefore, the indemnity provisions contained within the licenses do not govern any liability determination in this case.

The United States moves for summary judgment on the applicability of the license indemnification clauses to the damage caused by the Big Creek fire. The United States first argues that the Project 67 and Project 2175 licenses explicitly apply to the 12kV transformer, pointing to various general provisions in the licenses and to one specific provision which, according to the United States, operates to explicitly incorporate the 12kV substation into the licenses. SCE cross moves on this issue, asserting that the licenses do not explicitly cover the 12kV substation and/or the transformer. SCE points to, among other things, lists of structures and equipment contained in the licenses, none of which mention the 12kV transformers or substation. SCE also points to a map attached to the Project 2175 license which appears to indicate that a “substation” in the approximate location of the 12kV substation is “not part of the project.”

As additional support for its argument that the 12kV transformers are not covered by the terms of the licenses, SCE argues that FERC cannot lawfully assert jurisdiction over the 12kV transformers. Specifically, SCE maintains that the transformers feed lines that serve retail customers and are therefore part of the “interconnected distribution system” over which FERC has no jurisdiction. The United States objects to SCE’s characterization of the lines leaving the 12kV substation and maintains that the 12kV transformers are in fact part of the power generation system, not the distribution system, and therefore properly fall within FERC’s jurisdiction. In the alternative, even if the 12kV transformers do not technically fall within FERC’s jurisdiction, the United States maintains that FERC has “mandatory jurisdiction” over the transformers by virtue of the fact that the entire complex sits on federally reserved lands. The United States further argues that, even if there is no basis for FERC to assert jurisdiction over the 12kV transformers, the license provisions nevertheless render SCE liable for the damage in this case.

Finally, in the event it is determined that the license provisions do not apply in this case, the United States requests summary judgment on several alternative legal theories. First, the United States submits that, if the licenses do not cover the 12kV substation or transformers, SCE was operating that equipment unlawfully on government lands in violation of the Federal Power Act and laws and regulations governing use the of National Forest lands. Assuming SCE was operating the 12kV substation unlawfully on government land, the United States requests summary judgment on the ground that SCE would therefore be liable in trespass for the damage to the National Forest, regardless of the extent to which SCE was at fault for the fire. Second, the United States requests summary judgment on the ground that SCE is also liable, regardless of fault, under California Health and Safety Code § 13007.

V. DISCUSSION

A. Cross Motions for Summary Judgment Concerning SCE’s Liability under the Licenses.

1. Basic Regulatory Background.

The Federal Power Act authorizes FERC to:

issue licenses to ... any corporation ... for the purpose of constructing, operating, and maintaining dams, water conduits, reservoirs, power houses, transmission lines, or other project works necessary or convenient for the development and improvement of navigation and for the development, transmission, and utilization of power across, along, from, or in any of the streams or other bodies of water over which Congress has jurisdiction ... or for the purpose of utilizing the surplus water or water power from any Government dam.

16 U.S.C. § 797(e) (emphasis added). The Act defines a hydroelectric “project” as a:

complete unit of improvement or development, consisting of a power house, all water conduits, all dams and appurtenant works and structures (including navigation structures) which are a part of said unit, and all storage, diverting, or forebay reservoirs directly connected therewith, the primary line or lines transmitting power therefrom to the point of junction with the distribution system or with the interconnected primary transmission system, all miscellaneous structures used and useful in connection with said unit or any part thereof, and all water-rights, rights-of-way, ditches, dams, reservoirs, lands, or interest in lands the use and occupancy of which are necessary or appropriate in the maintenance and operation of such unit.

16 U.S.C. § 796(11). “Project works” are defined as “the physical structures of a project.” A facility must meet the statutory definition of a “project work” to be licensed by FERC. New York Power Authority, 98 FERC 61,033, 61,095, 2002 WL 61991, *1 (2002) (“The Commission has jurisdiction over qualifying non-federal hydroelectric project works, which are defined in Part I of the Federal Power Act (FPA). If a project work does not meet the definition, it is not subject to the Commission’s jurisdiction and therefore does not belong in the project license.”).

The United States argues that the terms of the FERC licenses may nevertheless apply to structures and equipment that are appurtenant to project works, even if those appurtenant structures and/or equipment are not themselves “project works.” There is some support for this assertion. In Lake Ontario Land Dev. & Beach Protection Ass’n v. F.P.C., 212 F.2d 227, 232 (D.C.Cir.1954), the D.C. Circuit noted:

According to the statutory definitions, “project works” include all the physical structures of a project, and “project” includes not only named types of structures, such as dams, but also “all miscellaneous structures used and useful in connection with said unit.”

But, this does not change the underlying rule that FERC’s licensing authority is limited to “project works,” not entire “projects”:

The Commission licenses facilities— dams, powerhouses, transmission lines, and other “project works” of various sorts — not projects as such. Care must be taken in any consideration of this statute lest an inadvertent shifting of the terms “project” (which is a whole development) and “project works” (which are structures) cause confusion.

Lake Ontario, 212 F.2d at 232. It appears to be well settled that under the definition of “project works,” FERC’s licensing authority ends at the “point of junction with the distribution system.” See infra at Part V.A.3. In other words, even if a particular structure or piece of equipment might under certain circumstances be considered appurtenant to a project work, if that structure or equipment is beyond the reach of FERC’s jurisdiction, FERC cannot license it.

In certain circumstances, FERC may assert a form of jurisdiction over facilities that do not meet the statutory definition. For example, FERC may review and then may grant an application to delete a facility that was at one time approved for licensing but no longer meets the statutory definition. See Great N. Paper, Inc., 97 F.E.R.C. 61,204, 61,893, 2001 WL 1471791, *2 (2001) (“The only way the Commission has jurisdiction over the reservoirs at issue is if they are project works of the downstream unit of hydroelectric development. They no longer are. Nor were they ever under license, which means that the Commission cannot exercise the kind of authority it may exercise with respect to the transition of a work or facility from licensed status to non-licensed status.”). It may be inferred from this rule that FERC may assert jurisdiction over the previously licensed equipment or structure until the agency has acted upon an application to remove the equipment from the license.

Two fundamental questions are presented here: (1) Are the transformers explicitly included in one of the licenses, and therefore are covered equipment until FERC approves an application to remove them from the license? (2) Assuming the answer to this first question is no, does FERC have jurisdiction to regulate the 12kV transformer that was the origin of the Big Creek fire?

2. Is the 12kV Substation Explicitly Covered by the Licenses?

If a piece of equipment was at one time approved for licensing, FERC may entertain an application to have the equipment removed from the license’s coverage. See Great N. Paper, Inc., 97 F.E.R.C. at 61,893, 2001 WL 1471791, at *2. If the licenses explicitly covered the 12kV transformers, it may be inferred from Great Northern Paper, that the terms of the licenses apply to the 12kV transformers unless and until FERC removes them from the license’s coverage. It is not disputed that prior to the Big Creek fire, SCE had not applied to have the 12kV transformers removed. It is hotly disputed, however, whether the licenses make any explicit references to the 12kV transformer, or other items the licensing of which would render the transformers li-censable.

The language of the licenses was briefed extensively in the last round of summary judgment motions. (Docs. 139, 159 & 176.) The parties reassert many of these arguments in the pending motions by exhaustively listing all the portions of the licenses that could arguably refer to the 12kV substation. For example, on the one hand, the government points to passages containing general language, such as a section of the Project 67 License which states that the license applies to “all lands ... constituting the project area and enclosed by the project boundary.” (Project 67 License at 13; USA UF # 5, 6, 10, 11.) In contrast, SCE points to lists of equipment contained in the licenses, none of which make any mention of the 12kV substation or any transformer that steps up 7.2kV power to 12kV. (SCE UF # 42-58.)

The parties advance three central arguments based on the text of the licenses. First, the United States emphasizes a reference in the Project 67 license to “small ancillary lines” and insists that this references lines that currently extend from the 12kV substation. Second, SCE points to a map that purportedly excludes the 12kV substation from Project 67. Finally, the United States notes that the 12kV substation is referenced in the application materials SCE submitted to FERC when it sought initial approval for Project 2175.

a. “Small ancillary lines.”

The Project 67 license provides:

Transmission Facilities

Two 220-kV, 3-phase, single circuit transmission lines emanate from the switchyard at Powerhouse No. 8. One is the intertie between Powerhouse No. 2A and No. 8; the other carries project power to the central switch-yard at Powerhouse No. 3 (FERC Project No. 120), where it enters Applicant’s interconnected primary transmission system. In addition, small ancillary power lines extend from Powerhouse No. 2A to Shaver Lake and to the top of the Powerhouse No. 8 penstocks. We find that these transmission facilities constitute part of the project as defined in Section 3(11) of the Act.

(Project 67 License at 4; Kimball Dec. at Ex. A (emphasis added).) The parties dispute whether the phrase “small ancillary-power lines” is intended to be a reference to any of the lines currently emanating from the 12kV substation (the Snocat, Manzanita, and Stevenson).

The United States asserts that a portion of the Stevenson line, which currently emanates from the 12kV substation, currently supplies power to the penstocks of Powerhouse 8. (USA UF # 15.) In addition, a portion the Sno-Cat line “was at one point the primary power supply to Shaver Lake Dam and still supplies power to Shaver Lake Dam.” (USA UF # 17.) There are certainly similarities between the “small ancillary lines” described in the Project 67 license and these characteristics of the Stevenson and Sno-Cat lines.

SCE insists, however, that Plaintiffs evidence is suspect and disputed. For the most part, the United States relied on the expert opinions of Mr. Mara to support the undisputed nature of these facts. SCE correctly points out that Mr. Mara’s opinions have been stricken by the court. The United States argues that these facts are present in other portions of the record. For example, the government points to deposition testimony given by SCE’s expert, Mr. Preheim, who stated that the Stevenson line supplies “backup power” to the penstocks of powerhouse 8, as well as to powerhouse 8. (Ex. 16, at 89:8-90:8.) Preheim also admitted that, if the power were to go out at Powerhouse 8, SCE would provide power to run the penstocks through the Stevenson line. (Ex. 16, at 92:1-9.)

SCE, however, presents a declaration from Mr. Preheim submitted with SCE’s opposition to the government’s motion for summary judgment. In that declaration, Mr. Preheim clarifies that he actually believes that the reference to “small ancillary power lines” in the Project No. 67 license is “confusing because it does not accurately describe any power lines associated with [] Powerhouse No. 2A as currently configured.” (Preheim Opp’n Deck, at ¶ 9.) Mr. Preheim further declares that he has determined that “the lines referred to were the Musick line which emanates from [] Powerhouse No. 2 and goes toward Shaver Lake and the Jumbo line which runs from Big Creek Powerhouse No. 8 to the top of the Powerhouse No. 8 penstocks.” {Id. at ¶ 8-9.)

Rather than responding to SCE’s objections with facts, the United States protests that SCE should not be permitted to create a dispute of fact by submitting a declaration from Mr. Preheim contradicting his deposition testimony. In support of this proposition, the United States cites School District No. 1J, Multnomah County v. ACandS, Inc., 5 F.3d 1255, 1264 (9th Cir.1993), which makes reference to cases, including Foster v. Arcata Assoc., Inc., 772 F.2d 1453, 1462 (9th Cir.1985) and Radobenko v. Automated Equipment Corp., 520 F.2d 540, 544 (9th Cir.1975), where the Ninth Circuit held that a party should not be able to substitute an affidavit alleging helpful facts, which contradict earlier deposition testimony harmful to its case in order to avoid summary judgment. However, the Ninth Circuit warns that the Foster-Radobenko rule “should be applied with caution.” Multnomah, 5 F.3d at 1264.

[T]he Fosier-Radobenko rule does not automatically dispose of every case in which a contradictory affidavit is introduced to explain portions of earlier deposition testimony. The district court must make a finding of fact that the affidavit was a “sham.”

Id. (internal citations and quotations omitted). Here, there is nothing in the record which indicates that Mr. Preheim’s second affidavit is a “sham,” which means baseless or frivolous. The declaration appears to be a good faith effort on the part of SCE to clarify Mr. Preheim’s otherwise confusing and ambiguous deposition testimony.

In the final analysis, the evidence concerning the meaning and identification of the “small ancillary lines” mentioned in Project 67 is disputed. Neither party is entitled to summary adjudication on this issue.

b. Project 67 map indicating that the 12kV substation is “not a part of this project.”

SCE cross-moves on the issue of whether the licenses explicitly cover the 12kV Substation/transformers. In support of this contention, SCE relies heavily on Exhibit K-5 attached to License 67, which is a map described as showing the “Project Area in the Vicinity of Big Creek Powerhouse No. 2A.” It is not disputed that this map identifies the 12KV Substation as “Not Part Of This Project.” (SCE UF #46.)

The United States insists that the Project 67 map only excludes the 12kV substation because the 12kV substation is a project work under the Project 2175 license. (USA’s response to SCE UF # 46.) The government also points out that

Powerhouse 2, which is a project work of project 2175 (but not project 67), is also shown on Exhibit K-5 with a dashed outline. In contrast, FERC Exhibit K-6 to the project 2175 license depicts the 12kV substation in the same location but with a solid line, as it does for powerhouse 2 and the other project works licensed under project 2175. Powerhouse 2A, which is a project work of project 67 (but not project 2175), is shown with a dashed outline.

(Id. (emphasis added and citations omitted).) Taken together, these two maps, Exhibit K-5 to the Project 67 license and Exhibit K-6 to the Project 2175 license, create a dispute as to a material fact: whether the 12kV substation is a part of Project 67, Project 2175, or neither. Summary adjudication as to the explicit exclusion or inclusion of the substation in the license is therefore not warranted on this ground.

c. The United States’ arguments regarding references to the 12kV substation in license applications filed by SCE.

The United States continues to point to numerous references to the 12kV substation in SCE’s application for the licenses. (See, e.g., USA UF 9, 12A-12C.) Any arguments based on the mention of the 12kV transformer in the license applications are not well founded. Even assuming, arguendo, that the 12kV transformer is included in the license, only FERC may determine whether a particular piece of equipment is a project work and is licensable. See also Dept. of Water Resources, 51 F.P.C. at 533, 1974 WL 188166 (“The mere fact that various facilities are proposed for licensing by an applicant is not sufficient reason to assume that all of such facilities are properly the subject of a license.”).

Neither party is entitled to summary judgment based on the face of the licenses. The government has failed to establish that the licenses explicitly include the 12kV transformers and SCE has failed to establish that the licenses affirmatively exclude the transformers. This issue remains for trial.

As a matter of contract law, the license terms are ambiguous. Beyond the above-discussed arguments concerning the plain language of the licenses, however, both parties place great emphasis upon the breadth and scope of FERC’s jurisdiction. Although neither party supports their jurisdictional arguments with an over-arching legal theory, the extent of FERC’s jurisdictional reach is relevant to the interpretation of the ambiguous licenses. SCE impliedly asserts that ambiguity in the licenses should be construed in SCE’s favor because FERC cannot lawfully assert jurisdiction over the 12kV transformers. In contrast, by insisting that FERC’s jurisdictional reach includes the 12RV transformers, the United States impliedly argues that the ambiguous license should be construed in its favor.

3. Does FERC have jurisdiction to regulate the 12kV transformer(s)?

One of the primary disputes raised by these motions is whether FERC has jurisdiction to regulate the 12kV transformers. This question breaks down into two separate inquiries. The first inquiry is a legal one: Under what circumstances, if any, does FERC have jurisdiction over transformers that step up hydro-generated power for ultimate distribution to retail customers? The second inquiry is factual: Do the 12kV transformers qualify as the type of equipment over which FERC has jurisdiction?

A review of the record and relevant caselaw suggests that neither party is entitled to summary judgment on the issue of whether the 12kV transformers fall within FERC’s jurisdiction.

a. Applicable Law: What is the reach of FERC’s jurisdiction?

The starting point for this jurisdictional inquiry is the agency’s enabling statute. The Federal Power Act authorizes FERC to:

16 U.S.C. § 797(e)(emphasis added).

As discussed, FERC’s licensing jurisdiction is limited by the statutory definition of “project”:

“[Pjroject” means complete unit of improvement or development, consisting of a power house, all water conduits, all dams and appurtenant works and structures (including navigation structures) which are a part of said unit, and all storage, diverting, or forebay reservoirs directly connected therewith, the primary line or lines transmitting power therefrom to the point of junction with the distribution system or with the interconnected primary transmission system, all miscellaneous structures used and useful in connection with said unit or any part thereof, and all water-rights, rights-of-way, ditches, dams, reservoirs, lands, or interest in lands the use and occupancy of which are necessary or appropriate in the maintenance and operation of such unit;

16 U.S.C.A. § 796 (emphasis added); see also Montana Power Co. v. FPC, 112 F.2d 371, 373 (9th Cir.1940). The point of demarcation between licensable and unlicensable equipment is the “point of junction with the distribution system or with the interconnected primary transmission system.” Critically, a “primary line,” falls under FERC’s jurisdiction, while a line that is part of the “primary transmission system,” is beyond FERC’s jurisdiction.

Here, the issue is whether the 12kV transformer that allegedly ignited the Big Creek fire lies on the licensable or the unlicensable side of this jurisdictional demarcation. It is not disputed that several lines (specifically, the Snocat, Manzanita, and Stevenson lines) emanate from the 12kV substation. It is disputed, however, whether any of the these three lines are part of the “distribution system or the interconnected primary transmission system.” Even if this initial question is answered in the affirmative, it is also disputed whether the 12kV transformer is the “point of junction.”

(1) “Primary line” v. “primary transmission system.”

To determine whether a line is a “primary line” or is part of the “primary transmission system”:

the test to be applied is that of the basic purpose of the line in relation to other facilities. In determining which of the many purposes of any given line is the basic purpose we must, therefore, look to the specific facts before us.

Re: Western Mass. Elec. Co., 39 F.P.C. 723, 731, 1968 WL 112463 (1968) FERC defines a “primary line” as follows:

If a line is used solely to transmit power from a Commission-licensed project to a load center, and if without it there would be no way to market the full capacity of the project, then that line is primary to the project. However, if a line serves both the project and a distribution system or interconnected transmission system, it is not a primary line.

Puget Sound Hydro, 109 F.E.R.C. 61,039 at 61,160, 2004 WL 2260913 at *8 (2004); see also Georgia Power Co., 39 F.P.C. 930, 931-32 (1968) (a facility cannot serve as both a primary line, over which FERC has jurisdiction, and a distribution system, over which FERC has no jurisdiction).

(2) “Point of junction.”

FERC has repeatedly held that its jurisdiction ends at the “point of junction” with the primary distribution system. To properly apply this rule, two legal questions must be answered: (1) Under a particular equipment configuration, which piece of equipment is the “point of junction” with the distribution system? (2) • Once this “point of junction” is identified, does FERC jurisdiction include or exclude the particular piece of equipment that is so identified?

A number of cases shed light on how a court should determine the “point of junction” with the primary transmission system. In MONTANA POWER COMPANY, 56 F.P.C. 3290,1976 WL 15138 (1976), the FPC considered whether its jurisdiction extended to several power lines emanating from a switchyard. A number of lines connected to a lOOkV bus (which is essentially a switching station containing lines and switches that all operate at lOOkV) within a switchyard. Two lOOkV lines (the Kerr-Thompson Falls A and B lines) connected directly to the 100 kV bus. For various reasons that were specific to the facts of the MONTANA case, the FPC found that these 100kV lines were distribution lines (i.e., they were not primary lines subject to FPC jurisdiction). Two other lines connected to the lOOkV bus, each through a 100/161 kV transformer. These lines carried power at 161kV away from the switchyard. Again, for reasons specific to the MONTANA case, the FPC found that these 161kV lines were also distribution lines (i.e., not primary lines). In contrast, however, a fifth line connected a 13.2 kV hydropower plant to the lOOkV bus through a 13.2/100 kV transformer. The FPC found that this line, including the 13.2/100kV transformer, and the 100 kV line leading from the transformer to the lOOkV bus were primary lines, and therefore should be included in the license. The FPC found, however, that the lOOkV bus was “common to both distribution lines and the interconnected transmission system” and that the FPC’s jurisdiction was “limited to that point of interconnection.”

MONTANA did not explicitly define what it meant by finding that its jurisdiction is “limited to” that point of interconnection. In other words, FPC did not explicitly address whether its jurisdiction included or excluded this point of interconnection (the lOOkV bus). It can be inferred from the case, however, that its jurisdiction excluded this point of interconnection because in the MONTANA opinion the FPC listed all those pieces of equipment that should be included in the license and the lOOkV bus was not included in this list.

Each side relies on MONTANA to support its position. SCE emphasizes that the FPC excluded the lOOkV bus as well as the 100/161 kV transformers feeding two of the distribution lines from the license. The United States emphasizes that the FPC included the 13.2/100 kV transformer that stepped up power from the Kerr plant and fed it into the lOOkV bus.

Lockhart Power Co., 11 FERC 61,287, 61,585, 1980 WL 22530, *2 (1980) provides additional guidance. In Lockhart, FERC found that a transformer within a substation was the point of junction with the distribution system and excluded from the license, while three other transformers were found to be part of the “facilities associated with the primary lines.” Lock-hart concerned two independent sets of equipment. First, a single transformer converted power from a 2.3kV generation source to 33kV, which was then sent on to a distribution substation. Second, a separate bank of three transformers also converted power from a 2.3kV generation source to 33kV. All three transformers then fed power at 33kV into a 33kV “bus.” The bus, in turn then fed power to several distribution substations and a switching station

The applicable factual description in Lockhart provides some additional information:

The project substation contains four 2.3/33 -kV transformers, Nos. 1, 2, 3 and 4. On its 2.3-kV side — the generator lead side — transformer No. 1 constitutes the point of junction with Lockhart’s distribution system serving the Lockhart Village distribution substation. Since transformer No. 1 serves as a “point of junction with the distribution system” within the meaning of Section 3(11) of the Act, it is not part of the project and will be excluded from the license. Transformers Nos. 2, 3 and 4, on the other hand, are part of the project within the meaning of Section 3(11). Power flows from the hydroelectric generators at the project through these transformers to the 33-kV bus on their high voltage side. The 33-kV bus is the point of junction with the 33-kV lines to the Adamsburg and Lockhart Mill distribution substations and the Monarch switching station. Thus, these three transformers are part of the facilities associated with the primary lines (the generator leads) through which project power flows before reaching the point of junction with the interconnected primary transmission system. Ordering paragraph (B)(2)(g) of the order issuing the license for Project No. 2620 is also being amended consistent with these findings.

11 FERC at 61,585, 1980 WL 22530, at *2.

The United States focuses on the second part of FERC’s reasoning, concerning transformers 2, 3, and 4:

Transformers Nos. 2, 3 and 4 ... are part of the project within the meaning of Section 3(11). Power flows from the hydroelectric generators at the project through these transformers to the 33-kV bus on their high voltage side. The 33-kV bus is the point of junction with the 33-kV lines to the Adamsburg and Lockhart Mill distribution substations and the Monarch switching station. Thus, these three transformers are part of the facilities associated with the primary lines (the generator leads) through which project power flows before reaching the point of junction with the interconnected primary transmission system. Ordering paragraph (B)(2)(g) of the order issuing the license for Project No. 2620 is also being amended consistent with these findings.

Id. (emphasis added). From this description it can be inferred that where a transformer (or a bank of transformers) steps up power from a lower-voltage generation source to a distribution voltage and then feeds this stepped-up power into a bus operating at the distribution voltage, the bus is considered the point of junction with the distribution system, not part of the primary line, but the transformers which feed the bus are considered part of the primary line and are licensable.

SCE, for obvious reasons, focuses on the holding concerning transformer No. 1:

On its 2.3 kV side — the generator lead side — transformer No. 1 constitutes the point of junction with Lockhart’s distribution system serving the Lock-hart Village distribution substation. Since transformer No. 1 serves as a “point of junction with the distribution system” within the meaning of Section 3(11) of the Act, it is not part of the project and will be excluded from the license.

Id. SCE emphasizes that it is the low voltage side (i.e., before the power is stepped up to the distribution voltage) that is considered the point of junction with the distribution system. It is not clear whether Lockart’s transformer No. 1 was connected to the distribution system through a bus or similar piece of intermediary equipment, but it is safe to infer that there was some structural distinction between transformer No. 1 and the other three transformers. This description is of limited precedential value, however, because it is so lacking in detail.

The United States also points to Consumers Power Co., 5 FERC, 61,141, 61,-336, 1978 WL 16136, *1-2 (1978), in which FERC confronted the following factual situation.

[A] 7.5kV line runs from the power plant bus to 7.2-kV/14.4-kV step-up transformers in the new 14.4-kV □substation. From there, a 14.4-kV tap line runs to two 14.4-kV distribution lines.

Id. The licensee argued that the 7.2kV/14.4kv step-up transformers were part of the distribution system and should be excluded from the license. Id. FERC rejected this argument, finding instead that

The “point of junction” with the Licensee’s distribution system is clearly the point where its 14.4kV distribution lines begin — after project power has been stepped-up to the distribution voltage. Accordingly, the 7.2 kV line from the power plant bus to the 14.4 kV substation and the bank of 7.2 kV/14.4 kV step up transformers constitute project lines and appurtenances.

Id. This holding appears to conflict with the portions of Lockhart cited by SCE, where FERC found that the low-voltage (or the “generator lead”) side of a step-up transformer was the “point of junction” and therefore that the entire transformer was unlicensable. For example, in Consumers Power, a “tap line” is situated between the transformers and the distribution lines. If this “tap line” is electrically similar to a “bus,” then Consumers Power more closely parallels the factual situation in MONTANA and the holdings from Lockhart cited by the United States. Interpretation of such a similarity from the available information requires analysis by an expert witness. No such evidence has been provided.

A few general rules can be elicited from the caselaw, even without expert testimony; despite inconsistencies between Montana, Lockhart and Consumers Power.

(1) First, whether a line is a primary-line or is part of the primary transmission is determined by examining the basic purpose served by that line.

(2) Second, once it has been identified that at least one line leaving a substation is part of the primary transmission system, a court must closely examine the relationship between the elements of that substation (from an electrical engineering perspective) to determine which pieces of equipment are licensable and which are not.

(3) Third, based on those cases which specifically describe the interconnections between the primary lines and the primary transmission system, a set of rules can be inferred.

(a) If one or more lines that are part of the primary transmission system feed off of a bus, that bus is the point of interconnection and is not licensable.

(b) If a primary line feeds into the bus through a transformer, that transformer is considered part of the primary line and is licensable.

(c) However, under certain situations, if a primary line feeds directly into a transformer which, in turn, feeds directly into the primary distribution system (i.e., without an intervening bus), the transformer should be considered the point of junction with the distribution system and is not licensable.

These “rules” are derived by interpretation of administrative caselaw many decades old. Federal district court judges do not, in general, possess expertise in electrical engineering, nor in the field of hydro-power licensing. What is clear from the case law is only this: there are no definitive criteria by which to determine if a step-up transformer is licensable as a project work. At the least, where a transformer steps up low voltage power from a generation source and feeds that power into a bus, which in turn feeds distribution lines, the transformer is part of a primary line and therefore falls within FERC’s jurisdiction. The question is whether this rule governs the 12kV transformer that allegedly sparked the Big Creek fire.

In the context of the pending cross-motions, the inquiry is whether there is undisputed evidence to permit application of this rule as a matter of law. For example, can the United States establish that the lines emanating from the 12kV substation are in fact primary lines, contrary to SCE’s submission that they are for distribution to retail customers? Alternatively, can the United States establish that the 12kV transformers feed into a bus, and therefore that the bus, not the transformers, is the point of interconnection? In either case, the United States might be entitled to summary adjudication on the issue of whether FERC would have had jurisdiction over the transformers.

4. Is the 12kV transformer that allegedly sparked the Big Creek fire subject to FERC jurisdiction?

SCE asserts that one or more of the lines emanating from the 12kV substation distribute power to retail customers and are part of the interconnected distribution system. SCE also asserts that the bank of 12kV transformers in the substation (including the disputed 12kV transformer) is the point of junction with the distribution system. The United States rejoins that none of the three lines currently emanating from the 12kV substation are distribution lines. Therefore, according to the United States, all of the equipment in the substation is licensable. In the alternative, even if any or all of the three lines are part of the distribution system, the United States asserts that the point of interconnection is actually a 12kV bus situated between the 12kV transformers and the three emanating lines. If this is the ease, the 12kV transformers sit on the licensable side of the jurisdictional line.

a. Are any of the three lines emanating from the 12kV substation distribution lines?

It is not disputed that three power lines currently emanate from the 12kV substation: Snocat, Stevenson,' and Manzanita. SCE, primarily through the declaration of Joel Preheim, focuses on establishing that at least one of three lines emanating from the 12kV substation is a distribution line. The United States objects to SCE’s evidence and points to several facts that suggest these lines should instead be considered primary lines.

SCE maintains that “the Manzanita line formerly served as a local distribution line to company-owned housing which was built from the 1910s through the 1930s in the area surrounding Big Creek Powerhouse Nos. 2 and 2A.” (SCE UF # 18; Preheim Dec. ¶ 6) Mr. Preheim, who lived in one of the cottages in the SCE housing area during the 1980s, maintains 'that the cottages “were equipped with meters to measure electrical power consumption for billing purposes” no: later than’the 1930s. (SCE UF ## 19-23; Preheim-Dec. ¶ 6.)

According to SCE, the Snocat line formerly distributed electricity to more than 75 percent of the light commercial and residential customers in and around the town of Shaver Lake. (SCE UF # 24; Pre-heim Dec. ¶ 7.) Preheim estimates that Shaver Lake first got electrical service from SCE on the Snocat line no later than 1940 and possibly in the 1930s. (SCE UF # 25; Preheim Dec. ¶ 7; Kimball Dec., Ex. H.) The Snocat line also supplied power to SCE facilities at Shaver Lake, such as Shaver Dam and certain SCE operated recreational facilities. (SCE UF # 26; Preheim Dec. ¶ 7.) In the 1980s and 1990s, the use of the Snocat line changed, during which time it provided about 40 percent of the customer service to Shaver Lake and served as a backup distribution source. (SCE UF #27; Preheim Dec. ¶ 7.) Currently, the Snocat line “continues to serve as primary power to Forest Service facilities and the Ponderosa Telephone Company at Musick Mountain near Shaver Lake and as a backup source for Shaver Lake’s customer load.” (SGE UF #28; Preheim Dec. ¶ 7.)

With respect to the Stevenson line, SCE maintains that it “provides a distribution system along Big Creek, serving residential and light commercial customers and providing backup power to certain SCE facilities.” (SCE UF # 30; Preheim Dec. ¶ 8.) Retail customers on the Stevenson line include Hogue Ranch, the United States Forest Service’s Clear Water Forest Station, and Wagner’s Mammoth Pool Resort, a retail store, restaurant and campground at Mammoth Pool Reservoir. (SCE UF # 32; Preheim Dec. ¶ 8; Wagner ¶¶ 2-5.) SCE maintains that the Stevenson line has served the Mammoth Pool Resort since 1958 and its operators have paid monthly bills to SCE since June 1, 1958. (SCE UF # 33; Declaration of Nelda Wagner ¶¶ 2-5; Preheim Dec. ¶ 8.) It is undisputed that the Stevenson line also supplies backup power to several Big Creek powerhouses operated by the Hydro Division of SCE. (SCE UF # 37; Preheim Dec. ¶ 9.) However, backup power is not continuously supplied to SCE powerhouses via the Stevenson Line. Rather, power from Stevenson may be called upon if any of these facilities become disconnected from their primary power source. (SCE UF # 38; Preheim Dec. ¶ 9.)

The United States challenges almost every “undisputed fact” proffered by SCE. The evidentiary dispute surrounds the evidence presented by SCE’s expert Joel Preheim, who speaks most directly to the purpose of the power lines emanating from the 12kV substation. In support of his expert opinions Mr. Preheim relies upon some evidence he has observed first-hand and some evidence he apparently gathered from the historical record and, perhaps, from other SCE employees.

The government objects generally to the admission of Mr. Preheim’s opinions on the ground that he bases his opinions on evidence about which he has no personal knowledge. But, it is perfectly permissible for an expert witness to base his or her opinions on the synthesis of second-hand information which may or may not be part of the record or even admissible:

Rules 702 and 704 allow properly qualified experts to testify in the form of an opinion about issues as to which their expertise may assist the trier of fact, even if the opinion embraces an ultimate issue of fact. Rule 703 permits the expert to base opinions or inferences on facts or data not admissible in evidence if they are of a type reasonably relied upon by experts in the field. Rule 705 permits an expert to give opinion testimony without pri- or disclosure of the underlying facts or data.

Bieghler v. Kleppe, 633 F.2d 531, 533 (9th Cir.1980).

The United States also objects on the ground that Mr. Preheim’s deposition testimony conflicts with the facts set forth in his declarations, upon which SCE relies upon to support its statement of undisputed facts. In general, the government’s objections are grounded in government counsel’s effective cross-examination of Mr. Preheim at his deposition on the accuracy of the dates provided in his declarations. Mr. Preheim repeatedly backed away from specific dates. (See USA’s Objections to SCE’s Evidence, Doc. 284, Attch. 1, at 13-19.) Mr. Preheim’s deposition testimony does raise disputes as to the accuracy of specific dates included in his declarations.

The dates are material because of a rule set forth in Great Northern Paper. 97 F.E.R.C. at 61,893, 2001 WL 1471791, *2 (“The only way the Commission has jurisdiction over the reservoirs at issue is if they are project works of the downstream unit of hydroelectric development. They no longer are. Nor were they ever under license, which means that the Commission cannot exercise the kind of authority it may exercise with respect to the transition of a work or facility from licensed status to non-licensed status.”). This case suggests that, if a piece of equipment was once covered by a license, FERC must approve an application to delete that equipment from the license before it loses jurisdiction over the piece of equipment.

It is undisputed that the 12KV Substation was initially built in 1926 to supply power for construction of other powerhouses, such as Big Creek Nos. 3 and 8. (SCE UF # 15; Preheim Dec. ¶ 10.) It also cannot be disputed that the 12kV substation (and the transformers within it) would have been licensable at this initial stage. However, it is SCE’s contention that the use/purpose of at least some of the lines emanating from the substation changed over time. As explained above, SCE maintains that noiv at least some of the lines serve retail customers. But, even accepting SCE’s classification of the current use of the lines, it is important to know exactly when these changes were made vis-a-vis the issuance of the most recent FERC licenses in 1959 (for the Project 2175 license) and 1978 (for the Project 67 license).

If the licenses were issued BEFORE the change in the use of the lines, then the Great Northern Paper rule suggests that SCE should have applied for those lines to be REMOVED from the license. It is not disputed that SCE never applied for removal and, accordingly, that FERC never granted such an application or removed the transformers sua sponte or by operation of law.

The United States has pointed to record evidence raising a dispute as to the dates provided by Mr. Preheim. The question then becomes: Has either party presented any additional undisputed evidence that definitively establishes the history of these lines? Neither party presents alternative evidence concerning the Manzanita line. For the purposes of this motion, neither party has established the date on which the Manzanita line first began to bill SCE employees living at Big Creek as retail customers.

SCE presents one piece of alternative evidence concerning when the Snocat line began to serve retail customers in and around Shaver lake: an excerpt from a book, Reflections of Shaver Lake. (Kimball Dec., Ex. H.) On page 121 of that book, the author provides a three-page “Shaver Lake Chronology” covering the period of time from 5000 B.C. to 1983. The entry for 1935 reads: “The dark ages end as electricity arrives at Shaver Lake Heights.” Id. at 123. Setting aside Plaintiffs many evidentiary objections to SCE’s reliance on this excerpt, it is simply not dispositive of the critical question: When did the Snocat line began to serve retail customers? The Chronology entry does not provide any details concerning the provision of power to Shaver Lake Heights, let alone whether that power was even provided by SCE. For the purposes of this motion, neither party has established the date on which the Snocat line first began to serve retail customers.

The factual backdrop for the Stevenson line is more complex. Independent of Mr. Prehiem’s statements concerning the Stevenson Line, SCE presents a declaration from the operators of the Mammoth Pool Resort. It appears to be undisputed that the Resort is served by the Stevenson line. Its operators, Nelda and Weymond Wagner state that they have paid monthly bills to SCE since 1958. (SCE UF # 33; Wagner Dec. ¶¶ 2-5.) In addition to raising several objections to the evidence presented by the Wagners, the United States points to an important independent fact that appears to be undisputed: The location of all the retail customers SCE alleges are served by the Stevenson line, is beyond where the Stevenson line passes from the 12kV substation to powerhouse 8 and draws power from that source. {See USA’s Objections to SCE’s UF # 30.) Although no party provides expert testimony that permits legal analysis of this electrical fact, it is enough to raise questions as to the “primary purpose” of that portion of the Stevenson line extending from the 12kV substation to powerhouse 8. Accord-. ingly, the “primary purpose” of the Stevenson line cannot be determined as a matter of law on this record.

The disputed nature of these facts makes it improper to grant summary judgment to either party on this issue.

5. What is the relationship between the 12kV transformers and these lines?

The character of the three lines emanating from the 12kV substation is a threshold issue to the factual inquiry: Assuming at least one of the lines serves residential customers and could be considered part of the distribution system, what relationship do the 12kV transformers have to this line? Do the transformers feed directly into the line (like the line excluded from FERC jurisdiction in Lockhart) or do the transformers feed into a 12kV bus which is the point of junction?

A critical electrical diagram, the “One Line for Operation,” SCE 004857, appears to indicate that the 12kV transformers connect to the Snocat, Stevenson, and Manzanita lines though at least one and possibly two separate busses. During oral argument on these motions, counsel for both parties expounded upon the nature and effect of these pieces of electrical equipment. This discussion is not evidence. Although the report prepared by Plaintiffs expert Kevin Mara, does discuss the existence of a bus, his report has been stricken. Even if Mr. Mara’s report was considered by the court, it does not clarify the situation, for it does not delineate between the transformers and the bus in any way that permits application of the Lockhart and MONTANA rule. No other record evidence bears on this subject or provides sufficient detail concerning the electrical relationship between the 12kV transformers and the three lines which currently emanate from the substation.

B. Does the 12kV Transformer Fall Within FERC’s Jurisdiction by Virtue of SCE’s Occupancy and Use of Reserved Federal Lands?

The United States suggests that, regardless of the scope of FERC’s jurisdiction under the cases discussed above at Part V.A.3, the 12kV transformer falls under FERC’s jurisdiction because the enclosure lies on federal lands reserved to the Sierra National Forest. The United States points to 16 U.S.C. § 817(1) in support of the proposition that FERC has mandatory licensing jurisdiction over the transformer. Section 817(1) provides: