$11 FEDERAL REPORTER, 2d SERIES
and workoff credit provision intended to "help in generating capital funds" was recently upheld by the Supreme Court in Mobil Oil." Second, in addition to these area rate increases, the Commission has engaged in national programs to raise prices for the purpose of enhancing sup- ply: its 1972 optional certification proce- dure and its 1974 national base rates. Third, New York points to the emer- gence of massive "drilling funda" assem- bled by producers from the general pub- lic as another post-1970 development which calls into question the importance of providing capital through advance payments,"
In Order 441, the FPC explicitly re- ferred to its Southern Louisiana and Texas Gulf Coast opinions and noted that the just and reasonable rates estab-
77. See 94 S.Ct. at 2350.
78. See Optional Procedure for Certificating New Producer Sales of Natural Gas, Docket No. R-441, Order No. 455, 48 FPC 218 (Aug. 3, 1972) (establishing the optional certification under which gas from welis sunk after April 6, 1972, may qualify for rates substantially in excess of prevailing area rates). That order had recently been upheld, with minor excep tions, by this court in Moss v. FPC, 164 U.S. App.D.C., 502 F.2d 461 (1974) (upholding the optional pricing procedure in new Section 2.75 of the Commission's General Policy and Interpretations with the exception of subsec- tion (e) which was invalidated).
The FPC first employed the optional pricing procedure in approving contracts between three producers and Tennessee Gas Pipeline Co establishing a basic rate which exceeded the area celling by 19e per Mcf and included additional annual escalations. See Belco Pe- troleum Corp., Docket No. CP73-293, Opinion No. 659 (May 39, 1973), reversed and remand- ed. Consumers Union v. FPC, U.S.App. D.C., 510 F.2d 656 (1974) (decision based on FPC's use of faulty cost estimate ranges and test year). The Commission has sanc- tioned higher prices under the optional pricing policy in a number of other instances. See Comptroller General of the United States, Need for Improving the Regulation of the Nat- ural Gas Industry and Management of Inter- nal Operations 28 (1974) (between August 25, 1972, and March 5. 1974, 24 of the 77 applica tions filed by producers for gas sales under the optional certificate procedures were grant- ed. 39 were still pending. 11 had been with- drawn and 3 had been denied).
Another action elevating the level of rates above that prevailing in area determinations
lished therein reflected "the required level of capital formation" needed to elicit "requisite gas supply." The Commission went on to conclude that the existing difficulty in capital formation "supports our continuation for the limit. ed period [until December 31, 1972] of the rate treatment of advance pay- ments." Despite this recognition that changes in rate structures would affect the need to extend the experimental ad- vance payments program, neither of the two subsequent Commission orders con- tinuing rate base treatment included a reassessment of the availability of ade- quate investment capital for gna devel- opment. In its opinion denying rehear ing in Order 465, the FPC asserted that the extension of the program was "a necessary complement to our other cf- was taken on June 21, 1974, when Opinion No. 699 established a single national base rate of 424 per Mcf for jurisdictional sales of gas from wells drilled after January 1, 1973, and for gas first dedicated to the interstate market pursuant to contracts executed on or after January 1, 1973. The national rate is de- signed to provide "the incentives to stimulate and encourage the unprecedented exploration and development efforts that will be neces sary to find and produce the requisite level of new natural gas supplies." Opinion No. 699, at 24. On December 4, 1974, the Commission Issued an order increasing the national rate for such gas to 50% per Mef. Washington Post, Dec 6, 1974, at 1. col. 2-4.
These national rate base orders were not in existence at the time of the latest action un- der review, Order 499 in which the FPC de- nied rehearing on February 22, 1974. But it should be taken into account in the proceed- ings on remand now ordered by this court.
The Commission has also utilized its power to grant special relief from area rates to in- duce further gas exploration and development. See George Mitchell & Associates, Opinion No. 649, issued February 21, 1973, remanded for further proceedings, Macdonald v. FPC. supra note 75.
79. See Brief for Petitioner New York at 19- 20 & n. 16.
80. See 46 FPC at 1179. See also Macdonald,
supra note 75, 165 U.S.App.D.C. at, 505 F.2d at 364 (noting that the area rate struc- tures have been set "to provide producers with a necessary but not excessive profit in- centive for gas exploration.").
81. See 46 FPC at 1180.
PUBLIC SERV. COM'N, STATE OF N. Y. v. FEDERAL POWER CO. 351 Cite as 311 F.2d 339 (1975)
forts to obtain additional supplies of nat- ural gas for the interstate market." This assertion was not accompanied by any findings or references to evidence in the record. Moreover, the FPC did not address New York's argument, prosented in comments filed in the rulemaking which culminated in Order 499 and based on submissions in other FPC proceedings which indicated that there was no longer a shortage of capital-at least with re- gard to crucially significant offshore are- as, where reserves are massive in extent, and may be committed by the federal government to the interstate market.M Like the defect in its analysis of the data summary of the reports by pipe- lines, the Commission's failure to assess the impact of its other responses to the gas crisis identified above (see text at footnotes 77 and 78) precluded its recent orders from constituting a meaningful review and evaluation of the advisability of extending the advance payments pro- gram. Instead of "coming to grips with issues" of central importance to the rule- making, the Commission seemed content to rely on interested parties' approval of the program." The Commission could not faithfully discharge its responsibility to provide "'appropriate protection' to the public interest in not paying prices for gas substantially in excess of those
82. Order of Clarification, supra note 65, at 4: JA 113.
83. This FPC order, as well as all of the others dealing with rate base treatment of advance payments, contains no discussion of the na- ture and extent of the capital formation prob- lems of gas producers or the probable impact of various programs, see notes 76-78 supra and accompanying text on the capital position of the producers. However, there is some indication in the record that small producers face capital shortages for which advance pay- ments provide an important source of relief. See, e. g. Order 465, 48 FPC at 1551 (citing comments filed by pipelines and small pro- ducers). Statement of the Independent Petro- leum Association of America in Docket No. R-466 [sic]), at 3-4, JA 106, 107.
needed to induce production of an ade quate gas supply" while ignoring the present capital position of the gas pro- ducers."
3. Advance Payments for Offshore Exploration and Development [7] We turn to the Commission's treatment of advances made in connee- tion with offshore production. Although New York repeatedly noted important factors that differentiate offshore from onshore advances, the Commission virtu- ally ignored the problem. The denial of rehearing in Order 465 and the discus sion in Order 499 responded to New York's argument by a bare reference to the total volume of proven reserves "from onshore as well as offshore." 7 The Commission's order denying rehear ing in Order 499 indicates that it feels no separate problem is presented by off- ahore advances.
New York alleges that the Commis- sion has again failed to distinguish be tween onshore and offshore advances. This argument has been considered in Order No. 499 as well as in the order denying rehcaring of Order No. 465, issued February 23, 1973 (mimeo, pp. 3-4) and needs no further discussion herein.
The FPC's brief seems to place considerable emphasis on the steps taken to assure that all interested parties have the opportunity to present their views of the program and to comment on the data compiled by the Com- See Brief for Respondent at 23-24 However, our prior decision contemplated that the Commission would do more than provide a forum for further debate. It assumed that the FPC would listen carefully to the argu- ments advanced, collect any necessary supple mental data, and subject the whole to "mean- ingful review, analysis, and evaluation" before extending the advance payments program be- yond December 31, 1972. See 151 U.S.App. D.C. at 317, 467 F.2d at 371.
86. See Macdonald, supra note 75, 165 U.S. App.D.C. at 505 F.2d at 363
87. See Order 499, supra note 6, at 5. Supp JA 136; Order of Clarification, supra note 65. at 3-4. JA 112-13.
68. Accounting and Rate Treatment of Ad vances included in Account No. 166, Advance
511 FEDERAL REPORTER, 2d SERIES
The Commission's treatment of ad- vances related to offshore gas blandly sidesteps all and any mention of the crit- ical fact of its plenary power to prevent diversion of gas from wells on leases in the federal domain to the interstate market." Whatever role advance pay- ments may play in attracting onshore gas from the intrastate and to the inter- state market, this justification is absent in the case of advances to offshore pro- ducers. Any reasoned assessment of the relation of costs and benefits of the ad- vance payments program involves mani- festly different calculations for offshore and onshore advances. The complete failure on the part of the FFC to focus on this issue is a failure to seck answers
Moreover, the Commission declined to respond to submissions by New York which cast doubt on the need for ad- vances to spur acceleration of the explo ration and development of offshore re- Berves In the most recent proceeding New York cited the statement of a ma- jor pipeline executive that the need to recoup amounts expended on offshore leases generated strong pressures for prompt development of reserves. This is in addition to New York's reference to an Exxon statement that there is no "shortage of exploration and develop- ment capital for the offshore areas of the United States," " The significance of the Commission's failure to come to grips with the separate problems posed by offshore advances is highlighted by the data that the great bulk of total advance payments has been concentrated in the Southern Louisiana Area, a region
that includes substantial offshore gas production."
Treatment of Advance Payments Which Result in Acquisition of a Working Interest
[8] In successive orders, the Commis- sion has reversed its position whether to give rate base treatment to advances which lead to the acquisition of a work- ing interest by the pipeline. In Novem- ber 1971, Order 441 denied rate base treatment to all such advances." In De- cember 1972, Order 465 allowed the in- clusion in the pipeline's rate base account of advances resulting in a work- ing interest in producers affiliated with the pipeline." In December 1973, Order 499 authorized rate hase treatment for advances yielding a working interest in either independent or affiliated produc- crs,"
New York consistently opposed rate base benefits where a working in- terest was obtained because that work- ing interest "compensates the pipeline for its expenditure, and there is no basis for contending that the cost of the pipe- line's investment should be borne by its consumers." N
New York alternatively requested that inclusion of advances in the rate base be accompanied by a corresponding credit reducing pipelines cost of service in the event a working interest procured with the advance generated a return, all to the end that the pipeline's stockholders would not benefit at the expense of con- sumers."7 In Order 441 the Commission required a reduction in the pipeline's cost of service for any realization resulting
for $975,000,000 of the $1,269,000,000 total advances committed); Southern Louisiana Area Rate Proceeding. 40 FPC 530, 545 (1968)
93. See 46 FPC at 1180
PUBLIC SERV. COM'N, STATE OF N. Y. v. FEDERAL POWER CO. 353
Cite as 511 F.2d 3 (1975)
from "[e]conomic interests other than working interests received as a result of making advance payments, where the re- lated advance payments have been ac- corded rate base treatment." " The FPC found that "while it is equitable for the companies to earn on advance pay- ments necessary to contracts for sup- plics, it would, however, be inequitable to deny any excess benefit from such advances to the companies' consumers through reduction of the of cost service." " In denying a similar credit for the benefits of a working interest atemming from advances included in the pipeline's rate base, the FPC did not ad- dress the problem of inequity or attempt to explain how it distinguished working interests from other economic interests. All the Commission stated was this:
Most of the parties responding [to] the proposal to credit the benefits of a working interest to a pipeline's cost-of- service opposed the provision. We In order to stimulate and en- agree. courage pipeline production, the pipe- lines should be permitted to retain these benefita.
Order 499 is not objectionable merely be- cause the rate base treatment given to working interest advances reflects a change of policy. The legal system docs not compel rigidity, or bureaucratic in- flexibility, least of all in an area like energy policy where flexibility may be essential in the public interest. It is the genius of the administrative process to be flexible in response to observed developments, and an agency may "switch rather than fight the lessons of experience." 183
However, the process of change in agency policy must be one that serves and does not erode the principle of rea- soned decision making. We quote from an carlier decision of this court:
An agency's view of what is in the public interest may change, either with or without a change in cireum- stances. But an agency changing its course must supply a reasoned analysis indicating that prior policies and standards are being deliberately changed, not casually ignored, and if ал agency glosses over or swervea from prior precedent without discus- sion it may cross the line from the tolerably terse to the intolerably
While here the agency's vice was not complete inattention to its prior policies, its discussion is so perplexing as to sow doubt whether this is a process of ren- soned policy making, with a change in direction put in effect for a navigational objective, or the confusion of an agency that is rudderless and adrift.
Specifically, the FPC relied on the same policy-of providing equal treat- ment to pipeline producers and independ- ent producers-to justify each of the three different positions taken in Orders 441, 465 and 499. In Order 441 the Com- mission relied on the policy of equal treatment (announced in Opinion 568) to withhold rate treatment from all work- ing interest advances. Order 465 in- terpreted Opinion 568 as resting on a desire to encourage "intensified explora- tion by pipeline producers,' 194 and found that this desire, and the limited freedom of pipeline-affiliated producers to negoti
103. See New Castle County Airport Comm'n v. CAB, 125 US App.D.C. 268, 270, 371 F.2d 733, 735 (1966), cert. denied. 387 U.S. 930, 87 S.Ct. 2052, 18 L.Ed.2d 001 (1967). 104. Greater Boston Television Corp v FCC. supra note 51, 143 U.S App D.C. at 394, 444 F 2d at 832 (footnotes omitted) 103.
See 46 FPC at 1180, referring to Pipeline Production Area Rate Proceeding. Opinion No. 368. Docket No. RP66 24. 42 FPC 7.38 (1969), aird sub nom City of Chicago v FPC. supra e 49
511 FEDERAL REPORTER, 2d SERIES
ate agreements to develop gas with others, made rate base treatment appropriate when a working interest was retained by a pipeline affiliate. In Order 499 the Commission pulled itself up by its bootstraps, and combined the change authorized in Order 465 and the policy of equal treatment of Opinion 568 to justify rate base treatment of advances result ing in working interests in independent producers. Other than noting that the cost to the consumer was no greater, the FPC did not explain why the special considerations which arguably pertain to pipeline producers call for rate base treatment in the distinct case of working interest advances to independent produc
We cannot say on the basis of the present record that the Commission has given reasoned consideration to the treatment which should be given ad-
107. See Order 499, supra note 6, at 6-7, Supp. JA 137, 138.
108. Mobil Oil v. FPC, 417 US. 283, 94 S.Ct. 2328, 2356, 41 L.Ed.2d 72 (1974), quoting Permian Basin Area Rate Cases, 330 US 747, 767, 88 S.Ct. 1344, 20 L.Ed.2d 312 (1968). 109. See, eg, Greater Boston Television Corp.. v. FCC, supra note 51, 143 U.S.App.D.C. at 393, 444 F.2d at 851.
vances resulting in the acquisition of working interests.
UNITED STATES v. DAVID Cito as 611 F.2d 305 (1975)
has neglected to provide a reasoned and responsive explanation of its decision to continue the advance payments program and to expand the scope of the advances eligible for rate base treatment.
[11] Petitioner urges that these ina- dequacies and the accelerating cost of the program to the gas consumer require that we couple any remand to the Com- mission with a prohibition against capi- talization of certain types of advances pending Commission findings with sub- stantial record support. In response to this suggestion, it suffices to adapt the words of the Morgan cases, and to say that a reviewing court should not view the agency with a hostile eye, like an "intruder"; but rather consider that court and agency combined are "collabo- rative instrumentalities of justice," each acting in the performance of its duty with due regard to the appropriate fune- tioning of the other in sccuring the stat- utory objectives. The distinctive author- ity of the courts of appeals to review the adequacy of record support for the agen- cy's orders is coupled with an obligation to combine supervision with restraint.114 It would not be in the public interest for us to exercise our judicial authority to scuttle in their entirety agency programs which may have certain aspects that pro- vide a beneficent impact on the gas sup- ply. It is our expectation that the Com- mission's on-going evaluation of the ef- fectiveness of the program will enable it to give prompt and careful attention to the problem arcas identified in this opin-
112. See Supplemental Brief for Petitioner New York at 23. New York requests that any remand be accompanied with a prohibi- tion of rate base treatment of future advances involving (1) offshore areas, (2) acquisition of a working interest, (3) exploration advances, and (4) agreements which do not require all gas to be dedicated to the advancing pipeline. 113.
United States v. Morgan, 313 U.S. 403, 422, 61 S.Ct. 999, 85 L.Ed. 1429 (1941) (Jus- tice Frankfurter); United States v. Morgan, 307 U.S. 183, 191, 59 S.Ct. 795, 83 L.Ed. 1211 (1939) (Justice Stone).
Defendant was convicted before the United States District Court for the Dis- trict of Columbia, June L. Green, J., of assault with intent to commit rape while armed, taking indecent libertics with a minor, and sodomy. The defendant ap- pealed. The Court of Appeals, Bazelon, Chief Judge, held that in making a com- petency determination it may be very useful for trial judge to question both the defendant and his counsel concerning the defendant's ability to consult with his lawyer and to understand the course of legal proceedings; that detailed inter-
115. In Order No. 499 the Commission an- nounced a general policy of limiting amounts includable in the rate base to the producer's total costs for exploration, development and production incurred within a reasonable time after the date of the advances. See note 39 and accompanying text supra. We commend the Commission's attempt to place an outer bound on the program by denying rate treat- ment to excessive advances However, even
if this general policy were refined and en- forced, it would not justify the continuation of the program in the absence of substantial record support.
Leasing ebbs, but drilling to hold high in U.S. gulf
DAN MCNABB
Gulf Coast News Editor
VIRTUALLY stripped of its prime unleased oil and gas prospects in the past 5 years, the Gulf of Mexico is shifting into high gear in drilling, developraent, and production on tracts acquired from 1970-75.
The federal Government sold leases to 4.88 million acres in the gulf for nearly $12 billion in bonuses in the first half of this decade. More than $7 billion went for 2.9 million acres off Louisiana.
The Journal predicted more than a year ago that the end was near for major leasing activity in the guli, particularly off Louisiana. Explorationists advised then that 20 years of federal
THE OIL AND GAS JOURNAL--JUNE 23, 1975
lease sales had milked the gulf of its most-attractive structures (OGJ, Apr. 22, 1974, p. 59).
Gulf lease sales since last October bear out this forecast. Lack of big prospects have cratered bonuses per acre, especially off Louisiana (see graph).
Now with only lean prospects remaining to be sold in the gulf, companies are looking at new U.S. offshore areas for domestic supplies of oil and gas. Industry spokesmen told a House ad hoc committee on offshore leasing in New Orleans June 7 that the future degree of U.S. energy independence wi!! greatly depend on frontier offshore re
Gul work builds. Though leasing in the gulf is down now, the heavy leasing
1970-75 -1,068 $11,905,647,283 48 $759,159,527 150,759 2,266.2-14 $164,300,587901 $8,710,166,422 105 $2,272,020,647
of the first half of this decade spells plenty of drilling and development activity there in the second half of the 1970's.
The U.S. Geological Survey reports that of 1,068 gulf tracts leased since 1970, 48 are producing, 105 are near producing status (shut-in, producible), and 901 are still under primary term. Initial terms on 528 tracts leased in 1974 and 1975 don't expire until 1979 and 1980, respectively. None of this year's purchases has been drilled.
Tracts acquired during 1970-75 accounted for 16% of the crude and condensate production and 23% of the casinghead and natural-gas production from federal acreage in the gulf in March.
USGS reports production under its jurisdiction in the gulf averaged 887,201 b/d and 9.46 billion cfd in March. A Journal tabulation shows 150,759 b/d and 2.27 billion cfd of the March output came from blocks acquired in the 1970's.
And as operators attempt to stave off declining gulf production, the new tracts will assume a greater share of the load. The share already is higher than in March, the latest nionth for which figures are available.
Since then, several additional tracts have begun production, and additional platforms on blocks already producing have begun to produce.
Last week, Kerr-McGee announced a pas-condensate discovery in the seyenth wildcat on the north offset, WC 522. The well flowed at the rate of 16.1 Meld and 168 b/d of condensate
through a in. opening from perforations between 7,732 and 7,748 ft.
The SLAM group originally acquired WC 522 for $3,030,000 and drilled six dry holes before Kerr-McGee and participants in WC 543 took a farmout. Kerr-McGee says additional drilling will be needed to determine if and where a platform will be set. Interest in WC 522 is now Kerr-McGee, 30%; Samedan Offshore Corp., 15%; Felmont Oil Corp., 12%; Marathon Oil Co., 10%; Burmah Oil & Gas Co., 10%; Amerada lless Corp., 10%; Louisiana Land & Exploration Co., 10%; and Case-Pomeroy Oil Corp., 3%.
Good money, bad money. It will be years before gulf investors have sufficient data to evaluate the wisdom of their investment in most lease purchases of the 1970's.
However, a handful of blocks already have yielded additional reserves in sands not detected by seismic exploration. Excellent returns are anticipated, for example, on several blocks in Eugene Island 330 field and East Cameron 271 field.
One other hand, many highpriced blocks have turned out to be duds. Offshore Florida appears to be the most glaring example. Between $500 million and $1 billion in lease investment cit Florida appears doomed by the current string of 14 failures.
Thus for tracts acquired in the 1970's for $1613 million have been turned back to the governmert. All are oft Louisiana.
Eugene Island 530. Production is
still building in Eugene Island 330 field, thus far the most significant acquisition in the gulf in the 1970's. The field was discovered in 1971 and continues to be extended.
In March, six blocks in the field averaged 88,350 b/d and 22S.5 MMcfd.
Block 330, on which Pennzoil Offshore Gas Operators Inc. has installed three 18-slot platforms and a production platform, averaged 41,424 b/d of oil and condensate and 113 MMcfd in March. A Pennzoil spokesman says production is expected to peak at about 40,000 b/d of oil, 7,000 b/d of condensate, and 125 MMcfd of gas by August 1975. Production commenced in 1973.
POGO has a 50% interest in EI 330, Mobil Oil Corp., 25%; Exxon, 15%; Mesa, 5%; Pinto, 2%; ECEE, 2%; and Texas Production Co., 1%. Including a $28,279,679 bonus in the Dec. 15, 1970 lease sale, expenditures on the block are estimated to be in the neighborhood of $110 million.
Five blocks adjacent to El 300 also are producing in El 330 field. Shell Oil Co's El 331 averaged 24,325 b/d and 29.5 MMeld in March. She!! paid $12,158,000 for the lease and installed a 27-slot and a 32-slot platiorm in
Exxon paid $2,221,603 for the south half of Eugene Island 314, which averaged 11,365 b/d and 6.1 MMcfd in March from one platform. Texaco Inc. and Tenneco 0:1 Co.'s El 333 averaged 8,448 bid and 22 MMc'd. The block cort $5,751,000. Texaco zad Tenneco Exploration Ltd.'s 150-50) E!
TH. CH. AND GAS JOURNAL -JUNE 2.1.
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