ML19329E741

Requests That Applicant Admit Encl Relevant Matters of Fact. Where Matter Is Denied,Applicant Is Requested to State Contentions Re Numbered Request & List or Identify Documents Relied Upon by 730315.Supporting Matl Encl

ML19329E741
Person / Time
Site:	Midland
Issue date:	02/12/1973
From:	Brand W, Clabault W, Leckie D JUSTICE, DEPT. OF
To:	US ATOMIC ENERGY COMMISSION (AEC)
References
NUDOCS 8006170898
Download: ML19329E741 (101)

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. u i t-UNITED STATES OF AMERICA THIS DOCUMENT CONTAINS BEFORE THZ

' POOR QUALITY PAGES ATOMIC ENERGY COMIISSION In the Matter of

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CONSU E RS 20WER COMPANY

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Docket No(. QO-329A

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baassuA Midland Units 1 and 2

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REQUEST FOR ADMISSICUS AND INTERROGATORIE3 AS TO T1070 SED CC'CENTIO'-iS Pursuant to Sections 2.742 and 2.740 of the Cc:tmission's Rules of Practice, the Department of Justice requests that Applicant admit the following relevcnt matters of fcct.

Where the netter is denied in vhole or in part, Applicent ic requested to stata its contentions uith respect to ecch numbered request and list or otheruisc identify the documents relied upon cnd the persons whcm Applicant presently antici-pates would testify in regard to those contentions.

The Department further requests that the above be completed by Applicant no 1cter than March 15, 1973.

1.

The retail market for electric power in Michigan's icwer peninsula is predominantly a descud acrhet for " firm" electric power, i.e., c1cceric power with c very high probability of continuous availcbility.

(In scme circuastances, industrial users of electricity clso create a der nd parket for "interruptible" pover--pouer with a lottor probability of cvailcbility.)

(The follering statements cre concerncd nich the cegineer-ing cnd economic problems encountered in making provisions for R006170 07 8

3 i-the marketing of " firm" power supply.

We believe that the significance of the torn " firm" power can best be understood by considering the history of the furnishing of electric power in Michigan and elsewhere in the United States.)

2.

Prior to the 1880's electric power in Michigan's lower peninsula and elsewhere was furnished in a few places from on-site generators located, for example, at large commercial enterprises such as department stores, hotels, or at industrial sites, ordinarily owned and operated by the user of electricity.

3.

Beginning in the 1880's," central-station" service began to be offered throughout the United States, including Michigan.

Central-station service describes an arrangement in which the owners and operators of centrally located generating equipment distributed and sold electricity to others at locations rela-tively close to the generators--where it was economically feasible to do so.

4.

Power rates to larger loads ultimately were formulated in two parts:

(a) " demand charge" in which a price was fixed for each hilowatt of peak load capacity based on the fixed costs of the plant, and. (b) " energy charge" in which a price was fixed for each kilowatt hour bared on fuel and other operating costs.

These are explained generally in Earnes, Economics of Public Utility Reculation, Appleton-Century-Crofts, New York,1942, pp. 325,339.

5.

Among the several advantages of central-station service over isolated on-site generation was reduction in costs of l

i plant by reason of diversity of loads.

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a, s.

6.

For example, if a commercial enterprise had a load of 50 kilowatts in the evening and 10 kilowatts in the morning and an industrial enterprise had a load of 50 kilowatts in the morning and 10 kilowatts in the evening, the two loads could be supplied by a single generator of 60 kilowatt capa-city uith the additional cost only of distribution wires between the generators and the loads.

7.

Another advantage was that a single crew could attend the centrally located generating equipment.

8.

The first central stations were confined to direct current systems in relatively small urban downtcwn areas.

With the advent of the alternating current motor and trans for=er, a single central station could feasibily serve larger and larger areas, because alternating current could be stepped up to a higher voltage for trcnsmission over greater distances with reduced losses and stepped down again at the points of use.

9.

Provision for continuity of service--or " firm" power--was one important problem remaining to be solved for isolated central-station generation.

10.

Where the source of supply was an internal combustion or steam engine or a steam turbine, the possibility of mechanical and electrical failure (" forced outage") was a significant factor affecting continuity of service.

11.

This possibility of cechanical and electrical failure or

" forced outage" of individual generating units persists today.

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.1 12.

At the present time, the average failure rate for diesel-electric engine generator sets is approximately 1% of the time, and individual instances of failure may keep a unit out of service for several months.

13.

The probability of failure for steam turbines varies from approximately 2% on average for smaller units with lower operating temperatures and pressures to approximately 6% on average for larger units with higher operating temperatures and pressures.

Somewhat higher rates prevail for " immature" units, i.e., within the first year or two after their instal-lation.

Federal Power Commission (FPC) 1964 National Power Survey, Part II, p. 406.

14.

Electric power supplied from a single steam turbine (with associated boiler and generating unit) with a " forced outage" rate of 2% of the time would normally be unavailable about 2 days out of every 100, or approximately a week out of every year.

15.

Power from a single such generator is not commercially marketabic as " firm" power in Michigan's lower peninsula or elsewhere in the United States.

16.

System failures in which failure of one element causes failure of another are called " cascading" outages, and power systems can be and are ordinarily designed to minimize the probability of such outages.

17.

It is thus.possible to arrange for connection of two or more generating units at a single central station in such a manner tl at the forced outage' of one of the generators will l

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not cause the other to fail; that is to say the probability of failure of two or more of the generators will be at random.

18.

In a central station with two generating units connected in this manner, the probability of the simultaneous but random forced outage of both generators where each generator has a failure rate of 2% is.02 x.02 or.0004, and the probability of the availability of power from at least one generator would be.9996, or at all times except.0004--or approximately 1 1/2 days out of every 10 years.

19.

Where such a central station contains two 10 megawatt (1 megauatt equals 1000 kilcuatts) generating units, and each generator has a failure rate of 2%, the probability of avail-ability of at least one unit or 10 magawatts of power would be.9996, and power from 10 megawatts of generating capacity would be commercially marketable as " firm."

Federal Power Commission Form 12, Schedule 16, refers to such capacity as

" assured capacity."

20.

Where such a central station contains one 15 megawatt generating unit and one 5 megawatt unit, each with a failure rate of 2%, the probability of availability of at least one unit would still be.9996; but only 5 megawatts of generating capacity would have that high a probability of availability, and the central station could thus market only the power from 5 megawatts of capacity as " firm."

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21.

" Dependable capacity" refers to the number of kilowatts that a generator can be relied upon to generate continuously except for forced outage and scheduled outage for maintenance.

22.

" Reserves" for a generating system of two or more genera-tors refers to the difference between " dependable capacity" and the capacity marketable as " firm."

23.

In an isolated central station of two 10 megawatt generators, the. dependable capacity would be 20 megawatts, 10 megawatts of capacity would be commercially marketable as firm, and reserves would be 10 megawatts.

Reserves are neces-sarily equal to the size of the single largest unit because that unit would not be available during maintenance or in the event of its forced outage.

24.

If the isolated central station had instead one 15 mega-watt generating unit and one 5 megawatt unit, the dependable capacity would still be 20 megawatts; but reserves would be 15 megawatts--again equal to the single largest unit at the station.

Assuming a 2% failure rate for each generator, 5 mega-watts 'of this station's capacity would have a.9996 probability of availability and 15 megawatts would probably be available

.98 of the time.

Only 5 megawatts of capacity would be market-able as firm.

25.

It would be possible to decrease reserve requirements by installing smaller units.

26.

For example,10 megawatts of " firm" power could be marketed by installing eleven 1 megawatt generating units.

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• 27.

This would probably not be an optimum power supply, how-ever, because there are economics of scale associated with un4t size increases, increased generating unit size.

As/the costs per kilcuatt and per kilowatt / hour decrease quite rapidly, particularly in unit sizes in the range of 1 to 10 megawatts.

28.

The size of units selected by the system planner is a compromise between the desire to utilize the largest unit size which is economically optimal and the desire to keep the amount of reserves to a minimum, consistent with maintain-ing the necessary level of availability of service.

(This statement applies to a lesser extent to " peaking" units, which are run only a feu hours during the year at times of highest power demand, and " intermediate range" units, which run for fewer hours than the " base load" or nearly-full-time-operation units.

Peaking and intermediate range units normally have lower capacity costs and higher energy costs relative to base load units, and are available in small sizes.

Peaking loads are often served by a number of small units located at the points of need.

29.

The necessity to maintain the equivalent of the single largest unit as reserves is particularly troublesome for a growing power system as shown by the following example.

1 30.

A system with three 2 megawatt units and one 4 megawatt

' unit would have a dependable capacity of 10 megawatts and a capacity marketable as firm of 6 (4 megauntts of reserves,

equivalent to larges t unit).

Assume the system suddenly 7

a.

obtains an additional 6 megawatts of load.

It cannot serve that load and maintain system reliability merely by installing a new 6 megawatt unit.

If it installs a 6 megawatt unit, its ' dependable capacity would increase from 10 to 16, but its capacity marketable as " firm" would increase only by 4 megawatts (from 6 to 10) as its reserve requirement would increase from 4 to 6 (the largest unit on the system is now 6 megawatts).

31.

Among this system's possibilitic s for building genera-tion to serve the new load would be (1) to install oio 3 mega-watt units (and lose economies of scale), (2) to install two 4 megawatt units (total 8 megawatts; 6 megawatts for the new load with the surplus 2 megawatts earmarked to supply future load growth; no additional reserve requirement), or (3) to install a 6 megawatt unit plus a 2 megawatt peaking unit to meet the increased reserve requirement (total dependable capacity would be 18 megawatts, reserves 6 megawatts [4 mega-watts original + 2 megawatts], and marketabic firm pouer 12 megawatts--6 mc gawatts for the original load and 6 megauatts for the new).

32.

The history of power supply from the 1880's to the 1910's generally showed a transition from isolated on-site generation to isolated central-station service (other than for some very large industrial plants with substantial power needs).

(Even today some very large industrial loads and some very small farm or rural loads remote from power company lines find it economical or necessary to utilize on-site generation.)

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33.

In the decade from approximately 1910 to 1920 the techno-logy of electric transmission progressed to a point where it became possible to tie tuo or more central stations together by a high-voltage transmission line into a single bulk power supply system.

34.

Mr. W. A. Foote, who controlled one of the predecessor companies of the Consumers Power Company, and his brother pioneered this technology in Michigan (possibly as early as 1906).

Interconnection of central stations in Michigan may have preceded the state of the art elscwhere in the country by a few years.

35.

Where two central' stations each with two 10 megawat t gen-crating units (and thus :

20 megawatts each of dependable capacity; 10 megawatts each of firm capacity; 10 megawatts each of reserves) are tied together by a high-voltage trans-mission line, they can share a common reserve.

36.

Ten megawatts of capacity--equal to the single largest unit on the system--will satisfactorily fulfill reserve or standby needs for the entire newly interconnected system.

37.

The resulting interconnected system is thus capable of marketing 30 megawatts of firm pouer, as co=parcd with a total of 20 megauatts of firm power (10 megawatts each) for the two central stations operating isolated.

38.

If two similar-sized central stations interconnect, in j

lieu of t'aking the benefits by uny of marketing additional firm capacity they may elect to take the bene fits by installing l

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a larger, more economic units without degrading reliability of service, as shown by the following example.

39.

Tuo central stations, each with two 10 megawatt units (and thus 10 megawatts each of reserves or 20 megawatts total), could interconnect, agree cach to continue to maintain 10 megavatts of reserves, and install 20 megawatt units in the future without degrading the reliability of service.

The combined reserves of 20 megawatts would be equal to the size of the new largest unit (20 megawatts) in the interconnected system.

40.

In lieu of obtaining the benefits of interconnection by way of marketing more firm capacity from existing facilities or by way of increasing the economic justification for instal-ling larger units, the benefits of interconnection may be

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taken by way of increased reliability, as shcwn by the follouing example.

41.

If two central stations (each with two 10 megawatt units) interconnect and each continue to maintain 10 megawatts of

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reserve and to utilize 10 megawatt units as the largest unit size, the interconnected system could withstand the simul-taneous but random forced outage of two generating units, and still market the same amount of fir = power but of even greater reliability.

The probability that three units would be out of service simultaneously would be a much louer order of probability, resulting in a greater probability of availa-bility of at least 20 megawatts.

The probability of forced 10

outage of three units is.02 x.02 x.02 or.000008.

The availability of at least 20 megawatts uculd be.999992.

42.

In practice, interconnection usually results in the enjoyment of a combination of all three kinds of benefits--

marketing additional firm capacity, installing larger generat-ing units, and improving system reliability.

43.

If the two interconnecting central stations remain under separate ownership and have equal bargaining power, they will probably split the bene fits equally.

44.

An arrangement which would carry out " reserve sharing" would require the construction of a transmission line and the execution of an agreement to sell " emergency power" cn cn if-cnd-when-available basis without any demand charge for idle capacity but only an energy charge for energy actually used.

45.

Such an agreement must also provide that each party will share fairly the " responsibility" of maintaining sufficient

" reserves" to maintain reliability on the interconnected system, either by maintaining a fair p6rtion of reserves on its own system, or by purchasing reserve capacity from other interconnected systems.

46.

Under such an agreement, where two central stations each "ith two 10 megawatt generating units interconnect, and the bargaining strength of the parties is equal, each would be required to maintain 5 megawatts as its " reserve responsibility."

47.

The reserve responsibility may be stated either in terms of an absolute number of megawatts or in terms of the percentage 11 I

4 of its peak load (the maximum power load delivered by the system at any one time) that each party is required to main-tain as reserves.

48.

If the reserve responsibility is stated in terms of an absoP te amount, the reserve sharing is commonly referred to as " mutual emergency support."

Thus, in the foregoing example each party would agree to maintain 5 megawatts of capacity for mutual emergency support.

49.

If the reserve responsibility is stated as a percentage o f p ea'.

load, in the foregoing example, it would be 10/30ths or 33 1/3% or 10 megawatts for the interconnected system and 5/15 or 331/3% or 5 megawatts for each participant.

This manner of determining the reserve responsibility of each party to a reserve sharing agreement was applied (with slight modifications) by the FPC and approved by the Supreme Court in Gainesville Utilities Decartment v. Florida Power Coro.,

402 U.S. 515 (1971), and will be referred to hereinafter as the " equal percentage reserves" or "Gainesville" formula.

50.

Under such an agreement for reserve sharing between two central stations each with two 10 megawatt generating units, if one of the parties had a forced outage of one of j

its generating units at the time it was marketing 15 mega-watts of firm power, it could continue to meet its marketing obligations from 10 megawatts of its own capacity and 5 l

megawatts of emergency power "if and then available" from the other party through its interconnection.

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51.

It could rely on doing so even though the " emergency power" would only be supplied "if and when available," since the probability that power from the other system would be not available (,02) at exactly the same time that the first system's second unit would be out of service (.02) would be so low (.0004) that the quality of power supply on the first system would not fall below that generally accepted as firm power.

52.

The other party to the interconnection would enjoy an equal advantage.

53.

The distance between the two central stations is one of the critical factors to the economic feasibility of any reserve sharing arrangement.

54.

If the distance between the two central stations is rela-tively small, the cost of owning and operating the transmission line necessary for the reserve charing will normally be less than the cost of constructing additional generating capacity.

55.

When the distance between the two central stations is relatively great, the cost of the interconnecting transmission line may approach, equal, or exceed the benefits from the reserve sharing or other coordination.

56.

Assuming feasible distances, four central stations, each with two 10 megawatt units, could interconnect and share reserves and market firm power with only 10 megauntts in

. reserve for the entire pool.

57.

Uhere four central stations, each uith tuo 10 megawatt units (80 megawatts total dependable capacity; 20 megawatts 13

dependable capacity each) share reserves, each need maintain only 2.5 megawatts of reserves (10 megawatts total reserves,

equivalent to the interconnected system's single largest unit) and can market 17.5 megawatts of firm power (1/4 of the 70 megawatts total for the system).

58.

The reserve sharing arrangement may be carried out by contract or by common ownership or control of these four central stations.

59.

If a fifth such central station were admitted to this reserve sharing pool or.J equal terms (thus agreeing to maintain the same percentage of reserves as the other four), each of the five central stations would need maintain only 2 megawatts of reserves (10 megawatts total reserves, equivalent to the inter-connected system's single largest unit) and could market 18 megawatts of firm power.

(Its reserves would be 1/5 of the 10 megauntts pool reserves or 2 megawatts. Daducting this frca 20 megauates dependabic capacity would leave 18 megawatts marketable as firm.)

60.

The newly admitted pool member would increase its capacity

.,arketable as fimm from 10 megawatts to 18 megawatts (out of a

its 20 megawatts dependable capacity)[ereserve responsibility would 1

decrease from 10 megawatts to 2 megawatts.

l 61.

Each of the four original pool members, however, would increse its capacity marketable as firm only 1/2 megawatt, from 17.5 megawatts to 18 megawatts, as its reserve responsi-bility would decrease only 1/2 megawatt, from 2.5 megauatts to 2 megawatts.

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62.

Thus, if the benefits of pooling reserves will be shared equally among all five pool members, regardless of the order in which they enter the pool, the potential benefits to the fifth central station seeking admittance are greater than the potential benefits to the four original members with which it wishes to join.

63.

The four original pool members might refuse to admit the fifth central station to the pool at all, or they might permit it to join only on contractual condition that the lion's share of the total benefits of pooling reserves flow to the original members.

64.

For example, under Applicant's " Holland" formula referred to below, a fifth central station with two 10 megawatt generat-ing units joining a group of four central stations each with two 10 megawatt generating units would be permitted to market only 11 megawatts of firm power from its dependable capacity, much less than the 18 megauatts marketable under the Gaines-ville formula and only slightly more than the 10 megawatts marketable under isolated operation.

65.

As the number of generating units in a system increases,

there comes a time when it becomes necessary to protect against the simultaneous but random forced outage of two or more generating units.

66.

The exact point at which this would be necessary is established either by judgment of the system operator or planner, or by statis tical methods which are capable of 15 i

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measuring reserve requirements in terms of varying risk levels

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of outage probability expressed either as a percentage of time, or by frequency and duration.

67.

Such methods include the " loss-of-load" method (percentage of time method) formulated by Calabrese, AIEE Transactions, Vol. 66, 1947, pp. 1439-50, Generating Reserve Cacability Determined by the Probability Method, and the loss of capacity method (frequency and duration) formulated by Halperin and Adler, AIEE Transactions (Power Annaratus and Systems) Vol. 77, August, 1958, pp. 530-44.

68.

Whether reserve requirements are measured by such statis-tical methods or by the simpler standard of maintaining the equivalent of the interconnected system's single largest unit as reserves, as previously explained, it is generally true that, when two o. more systems intcrconnect, for any given level of outage. risk the amount of reserves required for the interce.mected system is less than the sum of the reserves required to maintain the same risk level for the component systems operating on an isolated basis.

69.

When a small system pools its reserves with a larger system or group of systems b7 contributing reserves equal to an established percentage of its peak load, and thus need not maintain the equivalent of its single largest unit as reserves,

its problem of building economic new generation to serve load l

growth is reduced, as shown by the follo-ing example.

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70.

As discussed earlier (Item 30),an isolated system with three 2 megawatt units and one 4 megawatt unit would have a dependable capacity of 10 megawatts and capacity marketable as firm of only 6 megawatts.

To serve a new 6 megawatt load, it would have various compromise alternatives (see Item 31).

If, on the other hand, this system interconnects for reserve sharing with a larger system and its required reserve is, for example, 20% of peak load, capacity marketable as firm would be 81/3 megawatts out of a dependable capacity of 10 megawatts (10 megawatts is 120% of the possible peak load; possible peak load / capacity marketable as firm thus equals 8 1/3 megawatts).

The system could market 2 1/3 additional megawatts of firm power immediately, and it could serve a further 6 megauatts load merely by installing a sin 21e base load unit of 7.2 megawatts (6 megawatts for the load plus 20% of 6 megawatts to meet the required reserve percentage equals 7.2 megawatts).

Total dependable capacity would then be 17.2 megawatts and capacity marketable as firm 141/3 megawatts (17.2 megawatts is 120% of 141/3 megawatts).

71.

The electric power market throughout the United States in general over the last 70 years has been a growing market enjoying approximately 7% average annual compound grouth.

FPC, 1970 National Power Survey, I-3-3.

72.

Of importance to the electric power system planner is the absolute amount of growth annually, or the annual incre-ments of grouth, as a constraint on the size of new units to be installed in any system.

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o 73.

If the system planner chooses new units with capacity sufficient to meet two or more annual increments of load growth, the installing system vill be burdened by the fixed charges associated with the idle capacity until the time the unit is fully loaded.

74.

Two or more central stations can interconnect and install larger units without incurring such economic penalty, as shown by the follcwing example.

75.

Four central stations, each with an annual load growth of 10 megawatts could pool their load growth and could in the future install 40 megawatt units annually (assuming that i

they had resolved the reserve sharing problem satis factorily).

76.

If a fifth central station with 10 megaustts annual load l

growth were admitted to the pool, the pool could then install l

a 50 megcuatt unit each year.

77.

The fifth central station could then obtain its required 10 megawatts of load growth power annually frem a 50 megawatt unit and enjoy the significant economics of scale afforded l

by 50 megawatt units over the 10 megawatt units it would I

otherwise install.

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78.

The four original pool members, however, would gain only the lesser economic advantage of being able to install 50 mega-j watt units rather than 40 megawatt units.

79.

The obvious bargaining disadvantage of the fifth central station uith potent,ially more to gain than the four central stations uhose load growth pool it seeks to join is no less 18 i

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o present when the four pooling central stations have become financially as well as electrically integrated.

80.

The "ccordinated development" of generation made possible through pooling of load growth may be accomplished by a number of methcds, including:

(1) establishing joint ventures for the construction of large generating units; (2) staggering the construction of generating units among pool members, with the installing system selling " unit power" (power from a particular generating unit) at the costs of the new unit to the other members either for the life of the unit or for a number of years until the installing system can fully utilize the capacity itself; and (3) transactions in " surplus power"/

" deficiency power"--power surplus to the selling system after providing for load and reserve requirements, not identi-fied as frca a particular unit, sold with or uithout reserves to another system deficient in the power necessary to meet its load and reserve requirements, and but for the availability of which the buying system would have made plans to install new generating capacity.

81.

Where the parties have equal bargaining strength, a surplus power / deficiency pcwer transaction will usually take place at the cost of power supply currently being installed (i.e., the average costs per kilouatt of capacity and per kilowatt hour of energy of the unit being installed).

82.

Setting the sale price on this basis permits the buyer to obtain new generation to serve growth markets at a cost level appronimating the seller's costs for supplying grouth markets.

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83.

" Reserve sharing" and "cocrdinated development" are two important kinds of coordination among the several kinds that are practiced in the electric utility industry.

84.

Others include economic dispatch, or economy energy transactions, hydro-thermal coordination, maintenance coordi-nation, coordination of spinning reserves, and some not mentioned here.

85.

Common to all these kinds of coordination are two require-ments:

(a) high voltage transmission as the coordinating medium; (b) the willingness of other parties engaged in bulk power supply functions to plan or operate generating facilities in common.

86.

Hydroelectric generation is not as sensitive to the need for access to reserve sharing as thermal generators,

because hydroelectric turbine-generators have a low forced-outage rating and the economics of scale are not as significant.

87.

Houever, where hydrologic conditions provide limited amounts of water for generation at a hydroelectric site, access to coordination to obtain off-peak surplus energy from thermal generation systems can increase the value of the hydroelectric generation.

88.

The economically feasible hydroelectric sites in any area are limited in number.

89.

Sometime prior to 1910 Sk. W. A. Foote uns operating two or more central stations in parallel in Michigan's lower peninsula.

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s 90.

In 1910, Mr. Foote financially combined his interests in several central stations with those of Clark, Hodenpyl and Walbridge, who had interests in other central stations, and the Commonwealth Power, Railway & Light Company was formed.

91.

As of 1912, the Commonwealth Pcwer, Railuay & Light Company owned approximately 73% of the water power in Michigan's lower peninsula, as indicated in Appendix A hereto, a diagram from the 1912 Report of Commissioner of Corporations on Water-Power Development in the United States (following p.130).

92.

Another 13% was owned by the Indiana & Michigan Electric Company (now a subsidiary of the American Electric Power Sys tem). See Appendix A.

93.

The Commonucalth Power, Railway & Light Company was soon operating an interconnected power system combining the central stations of its operating subsidiaries.

For the purpose of operating generation and transmission, several of these central stations uere formed into a separate company known as the Au Sable Electric Company.

Its properties are indicated on the diagram attached as Appendix B.

94.

The Commonwealth Power, Railway & Light Ccapany, a holding company, included the operating properties indicated on lines 33-70 of the attached table from Senate Document No. 316, Electric Power Development in the United State s,

84th Cong.1st Sess. (1916), part 2, pp. 366-367 (Appendix C).

(In addition, the holding compcny controlled tro electric 21 a

railways which were major users of electric power.)

The remainding entries on the table indicate other independent systems in Michigan at that time.

95.

The his tory of the Consumers Power Company from the for-mation of its predecessor, the Commonwealth Power, Railway &

Light Co., until the present has been characterized by a continuing acquisition of ownership and control of central stations and operational integratien of central stations where distances made this feasible.

The constituents of Consumers Power Company are listed in Appendix D, an excerpt from E. H. Luther, Son of Service (a company history provided by Applicant on discovery in this proceeding).

96.

Among the acquisitions of the predecessors of Consumers Power Company were some small systems, both privately and municipally owned, already consisting of two or more central stations.

See Appendix D.

97.

Acquisitions in the 1920's included the Citizens Electric Co. of Battle Crcok, the Wolverine Power Co., owning hydro-electric plants on the Titibiwassee and Tabasco Rivers, a distribution sys tem in Linden, the S t. Johns municipal system, properties in Durcnd, Climax (municipal), Goodrich, Atlas, Bronson (municipal), Big Rapids, Greenville, Belding, Stock-bridge (municipal), Spencer (municipal), Athens, Shepard,

Ovid, Reed City (municipal), Wyoming Light and Power Company, Franken=uth, Dicondale, Farwell (municipal), Beaverton, St. Charles (municipal), Flushing (municipal), Addison, and 22 1

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s others, many of which were relatively small.

Sometimes the property came directly into the Consumers Power Company, and sometimes it came through some other corporate organization, such as a holding company (as exemplified by the acquisition of the Thornapple Gas and Electric Co.), or through another subsidiary (as in the case of Southern Michigan Light and Power Co.). See Luther, Sone of Service, pp. 327-328.

98.

The financial interests controlling these properties were affiliated with other financial interests controlling properties in other states too distant at that time for inter-connection and coordination with the Michigan properties, including the folicwing:

American Super Power Corp., United Board and Share Co.,

Corp., United Gas Improvement, Electric /Penn-Ohio Edison, Toledo Edison, and Ccamonwealth and Southern Co.

99.

Applicant was formerly a part of the Commonwealth and Southern Co.

The major components of the Commonwealth and Southern Co. included what is now Consumers Power Co. and what is now the Southern Company, a holding company that controls an integrated system of four operating companies.

100.

The Consumers Power Company was separated from the Commanttalth and Southern financial ama'.gamation in an SEC proceeding in the 1940 's.

The proceeding arose under Section

'll of the Public Utility Holding Company Act, which required the dissolution of holding companies consisting of more than one system of properties electrically integrated or capabic of being electrically integrated.

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101.

Among the more recent acquisitions of Consumers Power Company was N1chigan Public Service Company.

Acquired in 1950, Michigan Public Service Company operated an intercon-nected electric system in 16 counties in the northern part of Michigan's lower peninsula, including distribution service in Cheboygan, Gaylord, Ludington, Montague, Traverse City, and about 100 other smaller communities.

102.

Other acquisitions of Consumers Power Company were the Blissfield ' municipal system (1950), the White Cloud municipal system (1952), and the Bellare municipal system (1952).

103.

In 1956, Consumers Pouer Company acquired the Kalamazoo municipal system and approximately 1,000 retail customars.

104.

In 1959, Consumers Power Company offered to purchase, and finally did acquire, the Manton municipal system.

105.

In 1961, Consumers Power Company acquired the Grayling municipal electric syctes.

106.

In 1967, Consumers Power Company acquired the Rogers City Power Company through an exchange of stock.

107..In 1968, Consumers Power Company acquired the generating and distribution facilities of the City of Allegan, Michigan.

108.

At the time of the foregoing transaction, Allegan owned and operated a hydroelectric plant uhich it had constructed in the 1930's with PWA funds.

109.

Allegan also owned several thermal generating units which had been added from time to time to supplement the out-put of the hydroelectric generation.

24

110.

Immediately prior to the transaction, Allegan had sought a reserve sharing interconnection with the Consumers Pouer Company.

111.

In connection with urging Allegan to sell its electric system, Applicant advised the town voters that the city's system would not be able to construct and operate generating facilities as cheaply as it could purchase power from the Consumers Power Company.

112.

Applicant has made similar representations in efforts to acquire the generation and transmission facilities of Traverse City, Coldwater, and other cities in Michigan.

113.

Applicant has made offers, thus far not accepted, to purchase the electric facilities of other cities including Charlevoix (1962), Traverse City (1965), and St. Louis (1965).

114.

Applicant has succeeded in persuading some cities whose facilities it has not yet acquired to close down their generating plants and to purchase their bulk power supply from Applicant.

115.

As the period from 1830 to 1910-1920 saw a transition from isolated on-site generation to isolated central-station service, so the period from 1910-1920 to present has demon-strated the advantages of electric poner supply from central stations interconnected by high voltage transmission with other central stations operating either as a single company or as a " power pool" of several companies.

25

116.

Applicant, through high voltage transmission intercon-nections, had energency power arrangements with the Detroit Edison Company as early as 1928.

Later, after World War II, Detroit Edison, by contract, undertook not only to share reserves but also to coordinate development with Applicant under the Michigan Pool arrange-ment, on a basis which gave both parties full access to the benefits of coordination.

117.

The reserve sharing arrangements of the Michigan Pool at present are in substance those of the Gainesville formula,

(provided by applicant on discover"').

7 except that the arrangements are more detailed.

See Appendix E 118.

The Michigan Pool shares reserves with the Ontario Hydro Systet, a publicly owned system operating in the Province of Ontario, Canada, on terms which do not limit access to the benefits of coordination.

119.

Under Applicant's arrangements with Ontario Hydro, emergency power is re ferred to as " capacity power and energy."

Capacity power arrangements are made on the basis of a charge per kilowatt per day, rather than on a monthly basis as in Applicant's contract with the City of Holland.

There is no reserve responsibility, and only a daily capacity charge when emergency power is used.

Such an arrangement does not impose a substantial burden on access to coordination, as there is no charge for idle, standby or reserve capacity.

120.

The !Echigan Pool also shares reserves with Indiana &

Michigan Electric Co., Commonwealth Edison Co., and Northern 6

26

Indiana Public Service Co., as provided in an area coordina-tion agreement among the Michigan Pool companies and companies to the south, on terms which give each of them full access to the benefits of reserve sharing coordination.

121.

Under its arrangement with systems to the south, Appli-cant uses what is nominally a mutual emergency support arrange-ment.

However, the supported party pays no capacity charge for power in excess of mutual emergency capacity received, nor is the supplying party in default if it is unable to comply with a request for mutual emergency capacity because of an emergency on its own system.

Hence, in its e ffect, the errange-ment is similar to the Gainesville formula and superior to the mutual emargency support arrangements of Applicant's contracts with Lansing and Holland in providing access to the benefits of reserve sharing coordination.

122.

It is usual in most reserve sharing arrangements,

including those using the Gainesville formula, that the energy delivered with emergency power either is returned in kind or paid for at some reasonable rate, frequently out-of-pocket cost plus 10%.

This is the arrangement used by Applicant with systems to the south.

123.

In general, where two central stations or pools are of equal size, a pool agreement providing for mutual emergency support, wherein each party is obligated to furnish an equal number of, kilouatts in case of emergency, will ordinarily result in the sa=c sharing of interconnection benefits as the Gainesville formula.

27 I

124.

Where the system sizes are drastically different, however, agreements formulating the mutual emergency support in terms of an absolute number of megawatts, even where this number is determined by formula, usually provide a greater share of interconnection benefits to the larger system than it would receive under the Gainesville formula.

125.

Applicant has interconnected with the City of Holland under a formula, attached hereto as Appendix F, that incor-porates a mutual emergency support formulation in addition to a stated reserve requirement.

126.

Under what the formula calls " mutual emergency support,"

in/e f fec t Holland rrcmises firm. power without demand charge to Appli-cant in return for t,pplicant's promise of interruptible i

pouer, also without demand charge.

127.

The term " reserve responsibility" as used in the electric pcwer industry normally refers to a system's obliga-tion to maintain reserve capacity in excess of its load to meet the risk of forced outage (and sometimes other contin-gencies) (or to pay others to provide it with part or all of such reserve capacity).

128.

Under the Geinesville formula, the full reserve respon-sibility is expressed as a percentage of peak load.

Where one interconnected system falls short of meeting this reserve responsibility, it must compensate the system with which it is interconnected to the extent that the second system has reserves in excess of such percentage of reserve responsi-bility.

28 i

o 129.

Under the Holland formula there is an item referred to and defined as "RR" or " reserve responsibility."

This is not the full reserve responsibility under the Holland formula, however.

In addition to such reserve responsibility, the City of Holland (or any other electric utility who shares reserves on Holland formula terms) is required to pay addi-tional capacity charges whenever it requires emergency power in excess of a so-called " mutual emergency support capacity" (FESC) level.

See Appendix F.

130.

If the mutual emergency support capacity level'under the Holland formula is set somewhere above cero, then Holland's full reserve responsibility would he RR plus NESC plus the capa-city chcrges for emergency power taken at levels above MESC.

(Applicant deducts from its own reserve requirements in the

~

Michigan Pool amounts of MESC obtained from Holland and other small systems.)

131.

Under the Gcinesville formula, Holland 's reserve require-ment would be independent of the size of its largest generat-ing unit, and it could install larger units than it can justify economically under its present interconnection arrange-ment with Applicant.

132.

The Michigan Municipal and Cooperative Pouer Pool (hereinafter M-C Pool) consists of two generation and trans-

. mission cooperative systems, Northern Michigan (which supplies three distribution, cooperatives) and Wolverine (which supplies four distribution cooperatives), two relatively large municipal 29

'I

a I

s systems (Grand Haven and Traverse City), and four small municipal systems (Hart, Lowell, Zeeland and Portland).

133.

The present interconnection of the M-C Pool with Applicant is through one of the Pool members, Northern 4

Michigan, at Alba.

134.

The M-C Pool has over a period of years sought establish-1 ment of a reserve sharing coordinating relationship between its system and that of the Applicant.

i j

135.

Until the last two or three years, Applicant refused tu exchange emergency power on an if-and-when-available basis with the M-C Pool.

3 136.

Applicant presently sells the M-C Pool firm pouer on a 15 minute ratcheted demand basis.

This imposes declining j

demand charges for a year on the M-C Pool whenever it obtains power from Applicant to meet an emergency.

Under this arrangement the current conthly billing demand is the maximum 15 minute demand within the month, but not less than 60% of the highest demand uithin the preceding 11 months.

137.

Under its existing interconnection arrangement with Applicant, the M-C Pool's reserve responsibility cannot be less than the. capacity of its single largest generating unic.

138.

At the present time, the M-C Pool is negotiating with Applicant for a r.ew interconnection arrangement; and Applicant has offered terms including use of the Holland fortuia for reserve shcring.

30 s

139.

Under the Holland formula, it could be less expensive for the M-C Pool to refrain from building additional generat-ing facilitics over the next 15 years and to purchase instecd its additional bulk poaer supply requirements from Applicant, depending on Applicant's pricing decisions.

140.

In order to obtain project loans and approval from the Rural Electrification Administration (REA), G & T cooperativas must demonstrate that self-generation constructed with REA loan funds would be cheaper than purchased power.

REA Bulletin No. 20-6.

141.

An interconnection with Applicant on Gainesville formula principles would permit the M-C Pool aconomically either to justify larger-sized generating units in its expansion program or to defer installation of generating units for a few years and market additional firm power from enisting dependable capacity.

142..

Access by the M-C Pool to reserve sharing and coordi-nated development with Applicant would permit the M-C Pool to attain costs of firm bulk power supply lower than Appli-cant's charges for supply of identical service.

143.

Applicant has interconnected with the City of Lansing on a mutual energy support basis which restricts the city's ability to install larger units more than would interconnec-tion based on the Gainesville formula.

144.

For example, Lansing, while installing units of 160 megavatts in size, will be required to maintain reserves averaging in excess of 497. over the period 1972-82, and ranging 31 1

as high as 81% for one six month period. (At the same time, Applicant is able to install 800 megawatt or larger units and schedule reserves of approximately 18%, based on its own integration and its coordination with other systems.)

145.

The City of Lansing municipal electric system has in recent years attempted to obtain an interconnection with Applicant on Gcincaville formula terms.

146.

If Lansing obtained an interconnection with Applicant on Gainesville formula terms, it could sell substantial amounts of surplus power to other bulk power supply systems, including the M-C Pool.

147 Applicant has used its interconnection uith the City of Coldwater principally to encourage the city to purchase pouer at wholesale from Applicant in lieu of continued c:: pan-sion of the city's oun central station.

148.

Applicant's representatives have over a period of years urged city officials in Coldwater that it would be in the city's interest to purchase all its power supply at wholesale from Applicant rather than to expand its generating plant.

1 49.

Applicant has never offered Coldwater interconnection for the exchange of coordinating pcuer and energy.

150.

Applicant uses the Halperin and Adler method to measure risk of forced outage on its system.

See Items 65-68.

151.

The Michigan Pool also uses the Halperin and Adler method.

32 i

o 152.

Application of the Halperin and Adler methed to an interconnection by the Michigan Pool with any other sy: tem operating wholly in Michigan's lower peninsula would probably not indicate degradation of the reliability of the Michigan Pool uhere such system agreed to maintain a reserve percentage equal to that of the Michigan Pool, since those systems or any combination of them are small compared to the Michigan Pool.

In the unlikely event that the Halperin and Adler statistical test would show a degraded reliability and the need to cdd generating capacity to caintain the Pool's reliability standard, there would be no burden on the Pool if the other system supplied the entire additional amount.

153 Uhere the size of th2 other system is very small in comparison with the Michigan Pool, interconnection would not increase the reserve requirement of the Michigan Pool signifi-cantly even if the other system brought no reserves to the Pool.

154.

In such a case, where the other system maintains the same percentage of reserves as the Michigan Pool, the Michigan Pool could deduct frca its own reserve responsibility the amount of reserves brought to the Pool by the interconnecting smaller' system.

155.

Applicant has made no studies applying the Halperin and Adler test to the meshing of the probabilities of unit failure on its system or that of the Michigan Pool with the probabili-ties of failure of units of smaller electric utility systems in Michigan.

33 i

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156.

Under its contract with Detroit Edison, Applicant engages in comprehensive coordinated development of generation facilities, although there is some provision for individual development of generation in exceptional circumstances.

15 7 Except for an arrangement in uhich it has sold a portion of the capacity of its Ludington Pump Storage Plant to Common-wealth Edison, Applicant has not engaged in subst'_ntial coordinated development with electric utilities other than Detroit Edison, although some of its contracts with major systems operating wholly or partly outside Michigan (e.g.,

Indiana & Michigan Electric Co.) provide for the possibility of such coordinated development.

158.

Applicant has not engaged in any coordinated development with smaller systems wholly in Michigan nor do its contracts with such systems contemple te future cocrdinated development.

159.

Under programs of coordinated development, sales of capacity and energy cre made at the soller's long run marginal cost of capacity and energy, i.e., the cost of its current plant installations and the energy generated at those plants.

160 Applicant has entered into contracts for the sale of full or partial bulk power supply requirements to smaller systems in Michigan as customers, at rates claimed to be based on its average system cost.

161.

The economic effect of a sale of full or partial bulk power requirements at average system cost is significantly dif ferent than that of such a sale at long run marginal cost where the retail market is rapidly growning.

34

O,

e*

162.

Access to arrangements for coordinated development would permit an otherwise isolated system to compete more effectively for growth loads.

163.

Two general types of coordinated development would be available to the M-C Pool and other small systems in Michigan if Applicant were compelled to coordinate its development with those systems.

164.

One of these would involve coordination of both genera-tion and transmission uith Applicant and/or the Michigan Pool, with the M-C Pool financing portions of units installed by the Applicant or purchasing portions of the output of such units or purchasing surplus system power.

165.

An alternative form of coordinated development open to the M-C Pool is coordination of generation with other small electric utilities and industries in Michigan using the transmission of Applicant, to the extent technically feasible and after payment of a fair portion of the costs of such transmission.

166 Where small bulk power supply systems are relatively far apart, they may find that the costs of building connecting transmission make a coordinated generation and transmission program infeasible or only marginally feasible.

Feasibility is improved if they can find intervening systems to join in the coordination, since the intervening systems would share in the costs of the transmission (as well as add to the load).

Where there are no longer any intervening independent systems 35

o e

e (because they have been acquired by a dominant area system),

and the intervening load centers are served by the dominant area or regional system, coordination between the remaining small systems is relatively infeasible except under a program of joint transmission arrangements (or uheeling)with the dominant system.

167.

Prior to 1972 or 1973, Applicant's interconnection contracts with smaller syste=s in Michigan contained provisions restricting their interconnecticn with third parties.

The effect of these provisions was to limit interconnection cmong smaller systems where such was otheruise feasible.

166 As of 1970, Applicant owned and controlled 7,700 pole miles of transmission (44 kilovolts and above) consisting principally of 138 kv and 46 kv, with approximately 200 miles of 345 kv.

169.

Applicant owns and operates all high-voltage (44 kv up to but not including 345 kv) and extra-high-voltage (345 kv and higher) transmission in Michigan's lower peninsula except for the following:

(a) approximately 900 miles of 69 hv transmission and approximately 250 miles of 44 kv transmissions interconnecting the central stations of the M-C Pool; (b) transmission owned and operated by the Detroit Edison Company in the castern portion of the lower peninsula; (c) transmission owned and operated by Indiana & Michigan Electric Co. and Michigan Pqwcr Co. (subsidicries of the American Electric Pcuer System) in the southuestern corner of the 36

~

e peninsula; (d) a short seg=ent of transmission owned by Lansing connecting it to Applicant's transmission system; and (e) a small amount of transmission owned by the Alpena Power Company and a small amount owned by Thumb Electric Cooperative.

170 Under the Michigan Pool agreement, Applicant has the right to use Detroit Edison's transmission system in trans-actions with Ontario Hydro; and Detroit Edison has the use of Applicant's transmission system in transactions with systems to the south.

171.

In coordinating with Co=monwealth Edison and Northern Indiana Public Service Company, the Michigan Pool companies have made arrangements to use the transmission of Indiana &

Michigan Electric Company.

172 The 1970 peak load of the M-C Pool systet was approxi-mately 200. megawatts; of Lansing approximately 300 megawatts; and of Holland approximately 50 megawatts.

173.

The 1970 peak load for Applicant's system was approxi-mately 3500 megawatts.

174.

The 1970 peak load of the Detroit Edison Company system i

was approximately 5500. megawatts.

175.

The 1970 total peak load of the Michigan Pool (Applicant and Detroit Edison) was approximately 9000 megawatts.

176.

The 1970 peak load of the Detroit Public Lighting Commission, which serves -lighting and other municipal loads in Detroit, was approximately 110 megawatts.

37

~

.o 177.

No other el tric utility in Michigan's lower peninsula had a 1970 peak kvad exceeding 50 megawatts, exc2pt for i

subsidiaries c# the American Electric Power System.

178 In negotiating for reserve sharing and coordinated development with the Michigan Pool, the bargaining status J

of the M-C Pool is that of a 200-megawatt system bargaining with a 9000-magawatt sys tem--and, for reserve sharing purposes,

the 9000-megawatt system is a coordinated part of an even larger system extending over the Province of Ontario, Canada, and parts of Indiana, Illinois, and Ohio.

179.

Until recently, the Michigan Public Service Commission had not assumed jurisdiction over electric cooperatives in FHchigan, notuithstanding statutory authority to do so.

180.

It assumed jurisdiction upon the request of certain electric cooperatives, following their complaints of alleged unfair retail competition by Applicant.

181.

Approximately 10 years ago, the electric cooperatives requested state legislation to allocate retail territory.

182 At that time the Applicant opposed such territorial allocation and favored instead unrestricted retail competition.

183 Follouing its assumption of jurisdiction, the Michigan Public Service Commission initiated some regulation of competition between rural distribution cooperatives and privately owned electric utilities in Michigan.

184.

The IEchigan Commission has adopted a territorial allocation rule with respect to electric leads served by 38

\\

,g.-

L single-phase dis tribution lines; these are ordinarily small residential or small co==ercial loads.

The Commission's single phase rule is attached hereto as Appendix G.

185.

The Michigan Commission is now considering a three-phase territorial allcration rule, dealing with loads for service uith three-phase distribution lines; these are normally larger loads.

A rule has been proposed as shown in Appendix H.

186.

Applicant has urged, through the Michigan Electric -

Association, that locds of 75 kilowatts or.uore remain open to free and unrestricted competition between privately owned electric utilities and cooperatives.

187.

Applicant actually would prefer to keep loads of 25 kilowatts or more open to free and unrestricted competition between privately owned electric utilitics and cooperatives.

a 188.

Applicant favors competition with the cooperctives for large loads.

189.

The Michigan Public Service Co= mission has no jurisdic-tion over municipal electric utilities and does not regulate competition between municipal electric utilities and privately owned electric utilities.

190.

A provision of Article VIII of Michigan's 1903 consti-tution prohibited any municipality from selling outside its boundaries electric pouer in excess of 25% of the amount marketed inside its boundaries.

191 In a 1963 constitutional revisien, the Michigan Legis-lature as authorized to change this limitation.

See Article VII of the present constituticn.

39

s 192 By the terms of a 1972 Michigan statute, the foregoing constitutional limitation does not apply to the interchange of coordinating power -and energy among municipalities.

19 3 Rural electric cooperatives may not, by the terms of the Rural Electrification Act, compete to serve within cities at retail (with minor exceptions). 7 U.S.C. 5904.

19 4.

There is no limitation on the type of entity with which rural electric cooperatives cay interchange coordinating power and energy.

195.

There is free and open competition at retail within cities between municipal electric utilities and privately owned utilities that received rights to serve in those

~

cities under Act 264, Public Acts of Michigan 1903 (Foote Act).

196.

Applicant favors retail competition with municipal electric utilities uithin city limits.

19 7.

There are no laws li=iting competition in wholesale bulk power supply in Michigan.

19 8.

In general, the econcaics of serving any given load either with full requirements poner or coordinating power and energy depend on the size of the load, its rate of growth, and its distance from existing facilities.

199.

It is Applicant's policy not to compete for large loads with the Alpena Pcuer Company (a private electric utility to which Applicant furnishes bulk power at wholesale), even uhere it is econcaically feasible to do so.

40

r s

200.

It is Applicant's policy to seek to serve large loads within the municipal boundaries of Coldwater, Michigan, and other cities when and to the extent permitted by law, even where it has no Foote Act rights to serve within those cities.

201.

Coldwater and other cities have granted Applicant permission to serve large loads within their municipal bounda-ries in cases where their municipal utilities have found it economically infeasible to supply those loads.

202.

Michigan law permits municipalities to acquire the property of franchised public utility systems within munici-pal boundaries by condemnation after expiration of an outstand-ing franchise.

203.

The Michigan Public Service Commission may not restrict municipal entry into the electric business.

204.

It would be economically infeasible for a municipality to enter into the electric power distribution business if a competitivelypricedbulkpowersupplywergnotavailable.

205.

There have been no municipal entrants into the electric utility business in FEchigan's lower peninsula since 1925, except for the City of Zeeland.

206.

Sinyy 1925, several electric utilities have abandoned all (or nea. y all) of their generating function and became wholly (or almost wholly) distribution systems; but only one electric utility has added bulk power supply functions to what was previously solely a distribution system.

41

s.

207.

In general, the decision to abandon the generating function or to sell an entire electric utility has been made at the tice the utility's load had reached the limits of its existing bulk power capacity, and it required additional bulk power supply.

208.

Applicant conceded in 1970 that it was a "public utility" subject to the jurisdiction of the Federal Power Commission.

209.

Applicant has never conceded that its wholesale contracts are subject to Federal Power Co= mission regulation, although it has filed such contracts with the FPC.

210.

It is Applicant's position that it may not be required under any provision of state or federal law or regulation to sell wholesale power to a retail distribution system or to contract for such sale with any entity proposing to own or operate a retail distribution systoa.

211.

It is Applicant's position taat it is not required under any provision of state or federal law or regulation to share reserves under the Geinesville forcula with smaller systems i

operating wholly within Michiscn.

212.

It is Applicant's position that it may not be required under any requirement of federal or state law or regulation to coordinate development with smaller systems operating wholly within Michigan.

213.

Where a number of central stations are joined by high voltage transmission lines planned and operated as one 42

w system under common ownership, they are said to be " fully in te gra ted '. "'

214.

Where two or more fully integrated systems are joined by *ransmission lines, share reserves and engage in other types of oordination short of coordinated development, they are said to engage in " limited coordination."

215.

Where they also engage in coordinated development, they are said to engage in " extensive coordination."

216.

Representatives of the Michigan Pool companies (Appli-cant and Detroit Edison) have claimed that the coordination engaged in by the members of the Pool is the most extensive coordinaticn by any two or more compcnics in the United States, short of the ccordination of cerpenics centrolled by a common holding ccapany.

217.

The Midland units are to be connected with the remainder of Applicant's system by high-voltage transmission lines and integrated into that system.

218., The financial feasibility of the units is predicated upon such integration.

219.

The power marketed by Applicant as firm pouer comes i

from its integrated system, and the marketing arrangements do not identify the power as coming from any individual generating unit or units.

220.

Several units installed by Applicant and Detroit Edison are defined in the Michigan Pool agreement as " pool units" and are a coordinated develop =cnt of the Michigan Pool.

43 r

221.

Only systems which are very large and fully integrated in themselves or which have full access to coordination can use large base load fossil fuel or nuclear units to market competitively priced bulk power supply.

222.

At the present tice, except tihere a small electric utility in the area of Michigan's louer peninsula generally coextensive with Applicant's transmission system is reason-ably close to another small electric utility or group of electric utilities willing to coordinate with it, its only economical alternative to the purchase of poner in bulk frca Applicant is to construct its oun isolated bulk poner supply utilizing small generating units.

223.

At the present tice, Applicant is the only source of wholesale power from an integrated system available to actual or potential purchasers in the area of Michigan's icwer penin-sula generally cocatensive with Applicant's transmission system, encept as noted below.

224.

Wholesale purchesers close to the transmission system of the M-C Pool may purchase bulk pcuer supply from its inte-grated system uhich has capacity of approximately 200 mega-watts.

225.

Wholesale purchasers near the City of Lansing may purchase

. bulk power supply from that city's 300 megnunct system.

226.

Wholesale.purchascrs near the periphery of Applicant's system on the south and east may find it economically feasible to purchase pcuer from large coordinated systems close by, 44

such as Indiana & IEchigan Electric Co., N1chigan Power Co.,

and Ohio Power Co. (affiliates in the American Electric Power System); Northern Indiana Public Service Co., Toledo Edison Co., and Detroit Edison Co.

As the size of the whole-sale load increases, purchase from peripheral systems becomes economically feasible at greater distances within Applicant's area.

227.

While purchase from peripheral fully coordinated systemn may be feasible, some of those systems, such as Northern Indiana Public Service Co. and Toledo Edison Co. have a policy not to build transmission to provide service in Applicant's area and would even refuse to provide service should the potential wholesale custcmers be villing to construct trans-mission to their systems.

228.

Were small bulk power suppliers or groups of bulk power suppliers in IEchigan to have access to coordination on the same terms as those enjoyed by Applicant in its deal-ings with Detroit Edison, they could provide a greater degree of competition at wholesale and at retail than they are able to at present.

229.. There are three relevant product markets and a geographic area associated uith each.

These are:

(1) the retail distri-bution tarket uhere the buyers are consumers of electric power and the sellers are distribution utilities or distribution divisions of vertically integrated electric utilities.

This market is predominantly a market for firm power although 45

some industrial customers can use, and prefer to purchase, interruptible power (at a lower rate because no firm demand is imposed on the seller); (2) the wholesale or bulk supply market where the purchasers or users are the sellers in the retcil market.

This is also predominantly a market for bulk supply of firm power; (3) the area or regional power exchange.

This is a market for coordinating poner and energy.

Both the buyers and sellers in this market are sellers or suppliers in the seccad market.

230.

The geographic market for each of the foregoing is defined by the size of the load and the distance from existing facilitics :

(1) For the retail distribution market, it includes the suppliers ' existing customers and all customers located in territories capable of being served from existing facilities, or from added facilities where their cost bears some reasonable relationship to the anticipated additional revenues (for exampic, where the cost of facilities is equal to three times additional annual revenues); (2) The bulk supply. market is also defined by the size of the load and the distance from existing bulk supply _ facilities.

It includes all existing customers or bulk load centers and customers or load centers located a reasonable distance from existing facilities; (3) The market for coordinating power and, energy is defined by the size of the load, the distance from existing facilities and the nature of the transaction.

When intervening bulk poner suppliers are willing to make joint transmission 46 wt+

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~

arrangements (or wheel power), the distances for economically feasible coordinating arrangements are increased.

231.

The relevant retail distribution market in this proceed-ing includes all retail loads supplied by Applicant's dis-tribution properties and the retail loads of the other electric utilitics listed in Applicant's responses to the Attorney General's questions 9 and 10, with the following enceptions:

(1) loads served by subsidiaries of the American Electric j

Power System; (2) loads served by the Detroit Edison Ccmpany; i

(3) loads served by independent systems that are too distant economically to be served by Applicant, including Sebewing, Croswell, Detroit Lighting Commission, Wyandotte, Dowagiac, and Niles.

232.

The relevant wholesale or bulk supply market includes all uholesale leads supplied by Applicant to its own distri-1 bution properties and the wholesale loads of other electric l

utilities in Applicant's responses to the Attorney General's questions 9 and 10, with the follouing exceptions:

(1) loads served by subsidiaries of the American Electric Power Systom;

-(2) loads served by the Detroit Edison Company; (3) loads served by other independent systems that are eco distant economically to be served by Applicant, including Sebewing, Croswell, Detroit Lighting Commission, Wyandotte, Dowagisc, and Niles.

47

233.

In 1970 the relevant retail distribution market was approximately 4100 megawatts, of which approximately 3400 megawatts was supplied by Applicant.

234.

In 1970 the relevant wholesale or bulk supply market l

was 4100 megawatts, of which appro::imately 3550 megawatts was supplied by Applicant.

235.

In 1970 Applicant supplied approximately 807, of the retail market for electric central station service relevant to this proceeding and supplied approximately 85% of the wholesale market relevant to this proceeding.

?

WAisLACE E.1Ral.:0 i

WILLIAM T. CLABAULT DAVID A. LECKIE Attorneys, Department of Justice Antitrust Division February 12, 1973 Washington, D. C.

i r

,n.,

UNITED STATES OF A" ERICA BEFORE THE ATOMIC ENERGY CO:GISSION In the Matter of

)

)

CONSUSERS POWER COMPANY

)

Docket Nos. 50-329A

)

50-330A

(>Rdland Plant, Units 1 and 2)

)

CERTIFICATE OF SERVICE I hereby certify that copies of REQUEST FOR ADMISSIONS AND IhTERROGATG2IES AS TO IROFOSED CC;7E"TIONS, dated February 12, 1973, in the above captioned matter have been served on the following by deposit in the United States mail, first class or air mail, this 12th day of February, 1973:

Honorable Jero.r.e Garfinkel Atomic Safety and Licensing Chairman, Atomic Sa faty and Board Panel Licensing Donrd U. S. Atomic Energy Ccamission U. S. Atomic Energy Cornission Uashington, D. C.

20545 Washington, D. C.

20545 Chairman, Atomic Safety and Honorable ilur,h K. Clark Licensing Appeals Board Post Office Bo:: 127A U. S. Atomic Energy Com.ission Kennedyville, Maryland 21645 Hashington, D. C.

20545 Honorable J. Venn Leeds, Jr.

Mr. Abraham Braitman, Chie f Post Office Sc:: 941 Office of Antitrust and Indemnity Hous ton, Te::as 77001 U. S. Atomic Energy La=ission Hilliam Unrfield Ross, Esquire Keith S. Watson, Esquire Harold P. Graves, Esquire Unid, Harkrador & Ross Vice President and General 1320 Nineteenth Street, N.H.

Counsel Washington, D. C. 20036 Consumers Power Company 212 West Michigan Avenue Honorable Frank Kelly Jackson, Michigan 49201 Attorney General State of Michigan Joseph Rutberg, Esquire Lansing, Michigan 48913 Benjanin H. Vogler, Esquire Antitrust Counsel for AEC James F. Fairman, Esquire Regulatory Staff 2600 Virginia Avenue, M.U.

U. S. Atomic Energy Co= ission Washington, D. C.

20037 Unshingten, D. C.

20543

Mr. Frank W. Karas, Chief 2

Public Proceedings Branch

^

Office of the Secretary of the Co. mission U. S. Atomic Energy Commission Washington, D. C.

20545 DAVID A. LdGRIE I

Attorney, Antitrust Division i

Department of Justice Washington, D. C.

20530 i

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3LECTRIC POWER DEVELOPMENT IN' THE UNITED STATES I

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SECRETARY OF AGRICULTURE

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ELECTnle Pov.*En DEVELontENT IN T11E WITED SI ATES.

INDUSTRIAL, DY STATIONS AND BY STATES,101~-.Cantinued.

.TSICIPAL, AND MICI1tG A.WContimE,1.

A.-PL*r.LIC l'bl.In" PLANT 3--Cont. nut IJ *htieg rate Pn er r. r ; ar g.

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It srie.

7,g.3 f {flersa.l#g g,[.fy'(,' j' j,

Purchus power from-1*

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TABU: M.-ST.iTISTICS OF l'oV.In DEVELOPMENTS, PCULIC UTIt.

MIClllGALO,nthmed.

B -ML*NICIPA1 PLANTS.

Chirw gg Nameof twntert, v arri of mba!!stfes or ter er gg,pplie<l.

Natu ef rLat.

location.

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ELEC2n1C POWEn Dr.YELOP31ENT IN TIIE UNITED ST.nES.

371 yUNICIPAL, AND INDUSTRI.tL. BY STATIONS AND BY STATES,1915--Cu:timxd.

3NCIIIGAh"-Continued.

II.-11UNICIPAI. FLANT3.

I Ifors*

II >rm.

If *=e.

MN r*

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p.3 ge.

Ftstus of Lnd occuple J. Q,f[I 372% of P{fgI, P'('"u,ef rj

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r

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year. ' I therts.

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372 NLECTUIC l'on En DEVEL019 TENT IN TIIE L*NITr.D STATES.

TADu M.-STATISTICi Of POWER I>EVEI.OI'.'IENT8, PUl I.le n.

31ICIII GA h*.-Contin'ed.

Pel!LNICIPAL P1, ANT 5-CrL:r.ed.

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373

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s. CO.'.*iUMTU.*C.tT.i t 6.W.ety APPENDIX D

.. d,' '1' C O..' u' L'.'. 'a'.'. ':. a' e~~ a~ ','.- :. :.

w ^ '. '. ': '.

Incorporaled in 2.L ine in 1910 Licensed in ?.'ic~.-ip.

1913 b'here. t..i.:- !.

2.

!. itch I. a n ? a b;ic ic t e!c c 1903-1300 f;OTE:

r plAccd b !c:e *.:. der : 1-t!cn. Its t:ee u cre.;;;.:

J 3.

Citizens Light.' P o w e r 19 0 - 1.* 0 3 on a se ceed:g :2 e.

g c a P~~7 , ' - > "' - -

1 4.-

!.t i c h i n 2 :. F::fers? d il:: t.:s I P C 5 - 19 3 4 I

a tate!at:ct. c ; en.~f u d

-1 o.uisiticr.I ::: c-n 2::.f ca IUC I'32

• • 1#

5.

1.o w e r P e n i r.s c l 2 Fe c: l 's 2 7 - I r 0 :

Powe r 190 6 - 192 0 C.

Southern.tica. Lt;t: c:

s

'I. T h o : c a r.a. : : Gas & E!ce::ic 1905-1307 1.s n s i n ?.. F u e l & G a s t' L a r. s i re.' -G : t Li7h: '73 '06) 10 0C - 1 :'0 5

-f 3. M i c h t.: a n 1.1 : : ( ' :c h ic a !. ) : ^ 1 -: - 12 0 0 L

& G.

G r a n d *::.p s :: ':::.c ; c a FOws: 10.-;-1215 1

10.

C c :n ta a n w e 21:5 ? c *.e e r ( C o. } I L 4 - 1915 11, 5.t : in e w Pmt:: 20'9-1e1:

e 10.

Ba y Cit. P sw c: 1:*M -1915 13.

C on s e ;r.s. t r P.w c r (.'.: a c.. ) 1909-1915 1

1

-,14.

F1tn! E l e c :::c 1.'. - - 415 r

j Econotay Paae: C f. (G e r.c :::: ; Pla n t Owne: ship) 19 C9-1915 15.

Pon:1.t c F.w e r 13 M - 1315 5

d.

Au is ble El-s c 1 P:0.N c :: e n A T r a n s '. O p e r ) 1909-1915

'$*1315 t

C ',.. ; '.* '

4

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.'.l a n t i

• C J PO% e t O..

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j I

i

s. Af!Cils'GA:s ?Ubi.:C sik.*

MICHIGAN PUBLIC SERVICE COMPANY 1923-1950 East Jordan Elec Lt & Pwr 19 G1 -192 9 A r. t r i r. Li g h t & Power 19 06 - 192 3 N c r t h e rr. '.!i c h. P u b l'i c S e r v 1925-1928 Doync F&!ls Lt & Pur 1920-1927 The Mich. United Lt a Pwr 1922-192 7 l

The Stearn; Lighting & Pur 1901-1922

'I White River Pc' e r a Li'sht I f' 17 - I C+ 2 'i l

a l

Frugalc Power 1912-1917 Beyne River Fover 1907-1007 G ra yltr.; Elec tric 1901-1927 Elk Electric 1910 1927 The Cheboygan Elec Lt i Pur 1526-1923 P e ll s t e r. L t & Pur ?-1913 N.

& A.

Mc Ar thur O 1$39-1596

9TE; ta :.--c:.

r.

07.. e record.

e

s. CITIZENS L:GitT c~ !C:. 2.

CITIZENS LIGHT' h POWER COMPANY 1902-1938 1.c n a we e Coun ty L t'u P s r 102 s-193 5 l

Tccumsch Ele c tri-1 90-1925 The Toledo Edison (.!ich. ) 1927-1935 l

Totsdo Otta wa Beach 0. ' orthe rn Ay W 1916-1027 Decrfictd Electric Serv 1929-19,35 Electric L;ght !: Power in 1896-1000

)

l'OTE: v1 Indicates incomplete l

record.

i 4

S 1

e t

(

D

4. MICHIG.4N TEDER.CED LTILITLE.

l

. MICHIGAN FEDERATED UTILITIES 1925-1934 f

h! u t u a l G a s 15-5-1'}0:

Alt. Cicmens Ga s Lt 1909-1926 i

l hit.

C i c m e r. s G a s IE97-19J0 m

i G a s E n ;;i r.c e t i c. ; Service 1900-1905 i

Sault Stc. Ma rie Gl.E 1000-1905 i

I 11.

F.

Clerque 1s04-1900 Ply mou th N O:t:.. t!!c Gas 1314-1925 i

G r a tio t C.n.. t G a s 19 2 4 - 15 0 5 l

Alper.a Gas 191!-1905 I

Alpena Gas Lt c Fuel leva-1911 I

i Aloena Gas Light 1900-1903 L

Alpena Ga s 15 i5 -10 00

-l O w o s s o G a s L i s t.:

1655-1925 hlarshall Gas Lt;ht 1903-1925 I

hia tshall Ligh t 1316-1903 l

Marshall G a s !!74-15 20 i

G.:.

. ~

.,a

i. :...,. a : 1 M

l a t i Ga

.t o r a s t.:; 1:: -1: 4

'I e

eN w

,f,

o.s, x ss,

e*

s. LGnu N.VI.';itu ic:;i.:

LOWER PENINSULA POWER 1927-1934 Michigan Water Power 1925-1927 Lower Peninsula Power (Old) 1006-1927 l

Denzic Ceuaty Power 1912-1920 t

Frankforr Elec Light 1911-1913 l

Martin & Wayland Light & Pwr 1921-1026 i

Wayland Electric Light & Fyr 1'05-1921 Ecstcy Light & P o.w c r 19 0 4 - 19 2 6

~~ *

+.e.

e 4

4 0

o 4

-4 e

ie M

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4. 50t!TilERN M:GI!G.4N L GitT 4;' ini '

4 SOUTHERN MICH. LIGHT tc POY/ER COMPANY 1926-1930 t

d Pale D:sts 150;*1233 l West;t 11a (Men) 1315.:;03 L

d The kasters HyJto fles 19191J:6 l

l l Astley sy ste.i ;3:J..:J l1lattersalFa.et 14:(*1:15 l

r i

O 14:4-111 l

l Idmete Sy stem l Frescott Syste n !? !4 +11:3 h

l Ma11thei Lt & Fwr twit., s f-l Howart City Elec Lis.s 1894-1333 l

o ;i:5 1,;2 H

d McIr.de s s> ate m.*:.= 42 5 l

l Ha milta a La i F.e h

M111: roc k. Fews s ::r-s :2:t l l tiarme r 11e e Le i F w s 1914-1,t,

&lanetar: M acasta.

1 g,

lCearscrient Matth: 14e.-;i15 l

9 sterida e (Munic a ea:) 14 16:t l

lLakeCtajst-ta:tle;;;>;7 F

i l Cha s. Ostrander 19:!-13::

l e

'_22*14*1 p

M U sin a-Oast:st etsca.337 13:*

l lF(atrieCt.

A!!as Lt & Pst !$1f.15 !

j Lt : F=t

_ 1

]

jf.C. Itsee.. 8 1,;7 l

30. vic h.

Ja;;;f 1, 1-11*5 lGlea Cartrer o. ;3 1;.:

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s. :se. m l _l m,. !. -

]

l8steytaa!!ec&F.re1;.;4*:1: 7 !

E e a. e r t : c F e - s e l ',16 -..'

Cer.4:1ty P e. e s 16 0.

.,;8 I

it & 7si lita.;;;7 f

a a v e t: a - f e *. s;t e s e t:s c F w t.. :. ~ J.

l Wie f:a t e D!s tr 1.2 :*

• 1

• i l

l I t a v e r t J:;

,l l Nosti le an:h Lt '. Psr li.! 1);J H

-[le as e :t:s 111..t:s tar ; 1: 25 23;;l 1 C e r.tir.e n ta l L't.1siv 19:) ; r:f t

6 l

l Lake it 11ectrat !!*"-

1;i lGlatvisCett &P=

II:' li J ht t. f:tasantLta twe 3:(-le:1 d Litstit e:J (v astcar a11 ' J.: l e: 1

w. Mict. ;t & F w e ti;'. 4 2 5 e

4 dGalatsSyster. 1e 2 14:7 l

l La wte ace (M an) 1J16

• i:3 d icm;e'ni Sy ste m o 1J14-12:1 l

l Pasettle Mt:Ittg :lll=13:5 G a rJa a r *.6g 4 t 24;. 1;;*

l l 1:a I:stchtes a tti=:fil I

l 5ta:tss ;* -

s;) ifet.1321 l

P a t ri a t e s ( tt a r ) 1,13 = : 2 1 l

aeese tt g por:i:(.13:$

5tas.c44 Isec. kpr t

l 5 t s a s e a t it e s t. g-t,,..,01 l

d Asase quast 1400 21 s l

d Cutact (M;s:actp ain 153) 1107 l

d Meatsose Lt &awr ;i16*:i:5 l Ha rry M111e r 19:3 + 17:8 4

1 NOTE! m Ir.dicates 1.::m,: ste m,,,,.,,,

y,,g, t,,

,,,3,

3. ;;, l teCCid.

I

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h?!!s?

5 5 e *

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713

1. Tii0RNAPFLE GAi c.~ ELECTR::

THORNADD'7 GAS !.: EL EChRIC CO.NiPANY Leased to Cent;= cts in 1922 1905-1927 J

Hemicek Elec ( iunicipal) 1904 Elsic Electric (hiunicipal) 1911-1904 Execkenrid;e Electric (hianicipsi) 1923 hierrill Ele ctric (h'ur:icipal) on 1915-1903 Itha c a El e c tric (hiunicip al) 190.-1903 l

Ithac-Light a Power 1 E 96 -1904 l

Ithaca Electric Lightic; 1830-1506 I

C e r t r al hit c h.. Li c h t & F w r 1010 - 192 3 i

Alma Grein & Lumber 1907-1917 Censelida ted Lt a Pwr 1911 1916

- 11. 11. D oh e rty E s tr.te tA 1906-1911 i

4

- Harris Electric 1906-1911 l

Kit. Pleasant Elec n 1590-1906 Chippewa Const: ctica 1911-1916

!!a stin;s Gas e 1903-190G Thornapple Elec 1901-1906 Hasting s Elec Lt i Pwr 1991-1903 NOTE: sn Indic.tes inccmpie:

i reccrd.

-m y

r%-%

i J. t o

s..\\ticn:c.1x i:cn--

(Mus in) hilCHIG.AN 1.IGHT COhi?.ANY Incorporated in hiichigan 1914 Into Consumers Power Company 1922 15.

Saginaw City Gas 1901-1914

19. - The Bay City Gas 1399 1914 20.

Pontiac Light 1902-1914 21.

Flint G a s ' 9 0 4 - 1914 I

22.

Jackson Gas 1897-1914 i

23.

Kalamazoo Gas 1899-1917 4

)

24. Manistee Power & t. i g h t (Gas Prop.) 1912-1915

)

i 1

4 i

l i

I NOTE: This Le!J not i'.: conf:ned i

with The M'c'.. gan Ligh: Contpny.

(N. J.) a huiding company 19d4-1914

'.!' cru. :- t.

1.. d be for.: tir.u e c....:.:

t b :rs e is developed et si:ttecJiag page.

t a

F

+*

w w

3-

-?

a-r-w t

e

.v o-1 GRAND RAP.'DS.ML'5KEGON FC;t i?.

=

GRAND RAPIDS MUSKEGON PO'NER COMPANY 1904-1915 Frorn 1904-1936 Called G. R. Mttsh. Wr ter Pwr Elec Co.

i

' Grand Rapids Edison 1902-1915 i

Lowell Water & L1;ht 1582-19:'2 Lowell Wa ter 13!7-1692 Lowell Elec Lt t.A 1855-1532 Peninsula Lt P w r & !! c a t IS93-1902-West Mich. Ele c tric 1893 1902 G.

R.

Elec Lt & Pwr itEG 190L l

a Mich. Iron Works EL&P 1532-1854 Ediron Light of G.

R.

ISSC 1902 Fremont S y s t e :n 0 1905-1915 1

Ottawa Beach Water & Elec a 1908-1914 Macatawa Park System W 1905-1914 d

Muskegon River Water Pwr 0 1893-100G 1

l I'

NOTE: W Indicates incemplete reccrd.

\\

e

ov o

so. CO.\\t.MONIVE.4LTl! l'CL':.)

COMMONWEALTH POWER CO..fPANY 1904-1915 Grand Ledge Elec Power 1904-1907 W.

A.

Foo t e 1910 - 1910 1

Leslie Elec Lt & P w r l i 31 1910 Jackson Light & Powe r 15 93 -1911 f

l jackson Elec Lt Works 1:dS-16 93 l

Jarvit & Foote 1886-1585 Edisen Elec Lt I E E E 15.13 I

J.3ckson Elec Lt & Pvr O 1954-16t5 Allegan Light & Power m 1903-1911 Ba ttle Cicek Elec tric 1 29-1905 I

ij Battle Creek Elec Lt & P w r i fgs ; - 1 ? S 9 e

Ele c ( Ka l 5.':ll e y E,le c F r o.n ' 9 9 ) 19 5 5 - 19 0 5l K ala rw z o o Albion Elec Light 1S3d-1995 Ce re sc o '.t ill & !!yd r a ulic 1595-1905 Plainwell Power 1900-1905 Otsege Power 1903 1905 l

i

? i n e C r e e k P o.s e r l '. ;0 - i s u a

{

t i

i 1:0TE: m Indic:tes ir.ee..fl.te j

t.

e

. o.

n. sxctx.s:s n:t tr.

SAGINAW POWER CO.'.!PANY 1909-1915 Eartlett Illu tnin a tin g 1890-1910 s

r Saginau !.' nite d Ele c tric 19 0 3 W:. I t e r A b b o t t 1893-1901 l

i Sagina w Elec Lt & Pwr 13S9-1655 l

f.

Fc:t Waya: Jency Elec Lt 16Ed-1689

~

i Swif t Electric Lt 1851-1900 O

T e

l 7

I 1

?

e.:. v-o

n. BAY CITY IJWE:<

BAY CITY POVIER COMPANY 1909-1915 Bay City Traction & Electric (Elec Prop. ) 1903-1910 I

Traction & Power 1902-1303 Oay City Gas (Elec Prop. ) Since 1900-1903 I

Br.y County Electric 2391-190,0 Honte Ele c rte 1527-1391 s

Say, County Electric Lt 1569-1391 1

Swif t Electric Light (Day City Prop. ) 1951-1259 United Traction d 1900-1903 Bay City United Electric 1903 1

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NOTE: m Indicates incom-ple.te recerJ.

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a si. CO.NSC.'.fEKS PJtt'EX (.\\t:C!!l..*'

CONSUMERS 'POIER COMPAN'l (MICHIGAN) 1909-1915 i

4 Charlotte General Electric 1409-1911 l

Charlotte E1cetric 185;3-15:0.

j Shiawa ssee Light c: P o w e r I t' 0 0 - 1011

- Owosso i Corunna Elec tsici l d5 5-1911 Owosso & Ccruana Elec St. R y on 1805-1693 s

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C a l e d o n i.t Elec Lt & Pw r 16 SC -I S9 6 i

i Travis Dros. lo9e-1ced

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NOTE: m Indicates incorn-plete reccid.

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14. FLINT ELEC.7.;:

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FLINT. ELECTRIC CO.'.!P ANY 1908-1915 i

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Clio Electric m'1907-1915 Flint Light & Pow er 1903-13 0S I

Peoples Electric L:ght IS50-1904 t

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n. FoNTI.t: rs:r; PONTIAC POV.*ER CO.'!P.ANY 1909-1915 1

Pontiac Sta ndard Lighting 1393-1910 Pontiac Lij;ht (Elec Prop. ) 1932-1910 a

l Pontiac Ga s & Eicd tric li?9-1900 l

t f.t e d b u r y El e c L t l i. 9 s - 1 s 9 9 I-Edison Elec Lt & ?.l o t o r P w t 1553-1625 i

The Fontiac Gas Lt IS60-1539 j

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(Ele:rn: in;.v6td MANISTEE PC?.'IR & LIGHT COhiPANY (Electric Properties)

I 1912-1915 l

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T. M.

E d u a r 3 s ( 12 ) G.

H. 5 0 u r a e (10 12 )

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Northw estern ';ich. Lt & P w r ( *.l a r.. Lt & Traction) 1906-1912 l

e Ma nistc e G:s & Elec tric 19 02-1s 06

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CADILLAC WATER & LIGHT COMPANY 1905-1915 d

Cadilla c wa ter 1593 1905 4

Cummer Elec tric 1593-1905 t

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a. sact::.<:s* cary c.n SAGINA'.'." CITY GAS COMPANY

'1901-1914 a

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The Saginaw Ga s if 03-1901 i

Saginaw Gas Light IE63-1593 i

East Sagina w G a s I d 39 19 01 l

East Saginaw Gas Light 1603-1509 d

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nr. Tile BAY Cin' C.t:

J T-o THE BlY CITY GAS COhiPANY 1899-1914 4

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i Day City Gas Light 1263-1993 i

1 NOTE: See 12 Day City Power fo: clect:ic c:c.ecztv invelve-ment of the E.:y City Gas Co.

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PONTIAC. LIGHT COMPANY 1902-1914 Elec Prop. Went to Pontiac Pawer - 1910 l

Pontiac Cas e Electric 1500 1900 f.ie d bury Ele c tric L: 1395-1500 I

Edison Elec Lt & Motor Fwr 1538-1395 The Pontiac Cas Light 18C0-1519 I

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nr. FLINT CM FLINT GAS COMPANY 1904-1914

. City of Flint G a s 18 '10 - 19 0 4 e

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n.JA:XSON G.tf e

JACKSON ' GAS COMPANY 1897-1914 Ja c.kson 'is tl G a s a Fuel 15 5 7-1 E 9 7 Jac ks on Ga s 1.igh t.155 7 -lii?

N' c i G a s L t & Fuci 15i.7-1555

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n. Iuu.'.uzca c.c KALAMAZOO GAS COMPANY 1899-1917 Kalamazoo Gas Light 1356-;599 O

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no. hfAN157EE FC;LT.T 4? L!Gm -

(cas ir.;erus)

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i M ANISTEE PO'.','ER & LIGHT CCMPANY (Gas Proporties) i 1912-1915 i,

F. M. Edw ar ds ( 7 12)

G. H. Sourne ( 10-17-12) 1 P

2 Nor thw es tern Mich Lt & Pwr ( Man. Lt T r a c t) 1905-1912 l

Manistee Gas 1 Cle c tric 10 M -12 H

.I The Man. Fuel & Gas 1396-1302 l

Louis Sands 1939-1336 t

l The Man. Gas Lt & C o k e 15 3 4 - 13 5 0 f

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co:'tato 0.': rait:Dt.v5 cn.u.~s MISCELLANEOUS ADDITIONS NOT COVERED ON PRECEDING CHARTS

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rr,a ixm ORIGIN UtSCRil7 ION CO,',*st '.'. fir S 1915 1909 Central Power (Oscoda) 1915 1912 Sattsc Creek Heating & Lighting 1915 1905 Fenton Power & Light 1915 1907 m Dristo! Electric Light 1915 1902 2.e cl a n d ( ht u n i c i p a l) 1915 1914 Saginaw it e a t in g 1916 1831 E a s t T a w a s ( ht.u nic ip a l) 1916 1905 T aw as ( htu nicipal) 1917 1908 hia son ( htunicipal) 1917 1911 h!anistce Cc unty Electric 1917 1908 Western h!!chigan Power 1906

!!olly Elce ttic (Inde pe ndent P o w e r 1912 - 1916. I!olly 1917 Lighting prior to 1911) 1900 U nit e d Ele c tric ( 5!c ndo n ( hiunicipal) 13')0-1912 Burr Oak 1923 Electric 1907 1312) 1915 Lin de n Sys t e rn ( E.

P.

J a:n i s o n 1918-1323, W.

Wolverton 131E-191E, I n d e,' e n j e n t Pow er 1915 -1916) 1923 1923 1892 Citizens Electric -

1923 1896 Dur a nd Elec tric Distrib ution (Stanic! al) 1923 1892 St. Johns Elec tric Distrib ution ( Stanief r.a!)

1890 Bronson Distribution (htunicipal) (W. H. Friedrich prior 1924 to 1910) 1889 Big Rapids Electric (W. E. Donley Light i Po wc r l* 33 -190 0 1924 and liudnu t t Electric prior to 19 93) 1924 1919 e Atlas Distribution System 1924 1912 Goodrich Distribution System (h!unicipal) 1924 1916 Clim a x Ele c tric ( htunic ipal) 1925 1909 Stockbridge light & Power 1925 1907 Tower Electric 1925 1??1 F e..:e: Ele:tric L!;ht & P:ver l}:?

li)?

C.

~rL.;;t 1925 1903 htanc he st e r ( htunicipal) 132:

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I' at :

5

YEAR INTO CRIGIN DESCRIPTl0N CON OtERS

.1925 1905 o Athens (M unicipal) 1925 1919 e East Side Water Power 1925 1834 m Ovid ( Municipal) 1888 lonia Electric - af ter 1904 Ionia Water Power E!cettic 1925 1925 1904 New Grand Ledge Gas (Grand Ledge Gas prior to 1920) 1876 lonia Gas (The Ioals G as Light & Coke 13 52 -1924, Site owned previously by L.

F. Mi!!s !!13 -13 82 and the 1925 Ionia Gas Light prior) 1892 Rogue Rives Electric Light & Tower ( A.

Delbert Tower 1926 prior to 1902) 1920 1891 Reed City (Municipal) and Predecessors 1926 1919 Wyoming Light & Power 1920 1912 Frankenmuth Light & Power 1920 1922 Dim o n d ale ( M u nic i:>al)

'192C 1916 F arwell ( Mu ni cip al) 1885 N e w C h a r l'o t : e G a s ( W il li a m E. Ila r v e y 10 0 0.

W.

Engle &

J. !!. Findley 1300-1936 C harlotte Gas prior to 1902) 1927 1902 St. Charles (Municipsi) - (Robert Gage Coal prior to 1911) 1927 1927 1906 Grass Lake (Municipal) 1927 1895 FlushinS Distribution 1927 1905 The !! art Milling & Power (flushing) 1929 1922 m Evart Distribution 1929 1926 Tittabawa sse e Elec tric (F ar m Lines) 1929 1926 0 Tipton (Farm Lines) 1929 1929 Morenci Distribution System 1897 Centreville Water & Electric (Water sold 1934) 1930 1930 1903 Callier Light & Power and Predecessors 1930 1905 Addison Electric Distribution l

I?3:

M::aiian Elee.:

c:t 1325 10J:

1:s.

Scr_ : aue Sac ;;::

1931 j

1922 S pring Ar bo r Dis tr ib.a tio n 1i,.

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. ww YEAR INTO DEKRIPTl0%

CONSC.tlERS OKlGIN 1931 1926 Mesick Distribution a

1906 in Muskegon Traction & lighting Electric System (!f arne 1931 changed to Muskegon Gas 1930) 1909 American Electric 3ctvice (Freeport Electric 1919-1923.

1932 Freeport Milling 1909-1319) 4 1932 1920 Callum flydro Plant 3elding (Manicipal) (Celding Textile Mill in 1932 and 1915 vi 1933 Belding Dros. 1915-1332) 1935 1925 Greenbush Townrhip Light & Pove.

l 1930

]

1921 Beech Trce Power & Light IIllisdale County Electric (Indiana Electric Utility 1924-1926, 1917 vi 1930 Economy Electric e 1917-1924) 1936 1920 v) Northern Power 1936 1921 Munger Power & Light 1930 1906 rierse y Distribution 1937 1910 L1 !!ar rison Ele c tric S yst e r.1 1941 1922 flarmony Electric 1921 Sellevue Distributi:n (Municipal) 1946 1950 1898 Blir field (Municipal) 1928 Frederic Distribution (William Leng. Electric Service) 1951 i

4 1951

.1918 City of White Cloud (Municipal) 1912 Bellair e ( Municipal)

- 1952 1940 Stanton Cas (Scrying Stanton. S he rid a n. Crystal. Cedar 1953 Lake. etc) 1956 1895 Kalama zoo ( Municipal) 1899 City of Manton (The municipal system started in 1917.

Also there was Manton Electric Co. in 1917. Between 1899 and 1917 there were various individuals named 4

1959 Wheeler. Billings. Phelps and Saker) 19C1 1940 Cit y of G r a ylin g ( Municipal) 1 n$OIII E

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APPENDIX E I

a P

49

Ju I

1:OTES OI: !*ICHICA:* ELECTRIC PC'..'E3 FCOLI: ^, AGREEvE: 7 Tnis Agreement is divided into two main parts.

Part I generally covers tho' objectives and the oblications of Consumer: Power Company and The D2troit Eficon Co pany. Part'II is composed of appendices and the t

. procedures for irplementing the Agreement. ' nis division into two parts was nado with the cbjective of establishing general principles in Part I 1

with the idea that these principles reald be modified only infreqc.cntly, l

if at all.

It was recognized that the appandices and inple:r.cn?. tion pro-cedures would require frequent changes and Part II is designed with this in mind.

i-l Part I contains sixteen articles, se:-c of which are so-called

" boiler plate," ani general requircr.cnts for any such Agreement. Folloting is r. description of there articles and certain items will be discussed in co e detail.

Article I covers the (;cnaral obliga ti.ons and it is noteworthy, I 4

4 1

4 a

believe, that even though this document was executed in Decc=ber of 1062 4

the irportance. of reliability was properly' recognized. The very first t

oblication is that "cach of the partice hereto recognizes a mutual interect and advantage in maintaining a continuous and uninterrupted supply of elec-1 tric power and encrcy available'to cuctomers of both the parties hereto."

h Tne next twin General obligation is that new r. sources and cystem opera-L

. tions will be carried forward on a coordinated basis.

!!cxt is the

... ~.

_..-.-.r.-

6,-.

oblication to share the cap.ac..i.ty from co-c..al.l.e.d p:ol. unite. althouch such n

j nnits are to'bc engineered, conctructed and owned by only one party.

Tnis J

[

iten covers cerctentio.21 units as well a: cencrating unit "hwing unu ual

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In the appendices setting up 'the charing of pool unit capa-city, three levels of rccerve are cctablished. The larccr rccerve ic called forecasted _pcol recor/c and is the result of the relation betueen pool load 'and capacity including the pool unit. The next lower level of reserve is planned pool rc:c.rv.e and this is the rescrie level that would i

be attained if the precice sized new unit were available and economically i

desired. The lovest reserve level is m..i._n.i..n.un.,to.ol. reserve and this is the 0

level below which it is believed serious jeopardy to load carrying capa-bility nicht exist. Tne principal capacity equalization charges arc made l

to adjust the, relationship between cach part.y's actual reserve.and the three levels of reserve just enumerated.

i In making the charces for capacity equalization, t.hree levels of j

__ charge rate.s. are.provided. Tne first is the base rate., the second is one and one _h.a.l_f _ti_me..s_ t.he.~bacc r.at.e and the third is tuo ti-.e_r the.._ base rate.

J The base. rate is used then onc' party's rocerve drops below the forecasted

~.-

.Y reserve but the pool reserve renains above the nini7.:n reserve. The base a

rate is agreed to betwcon the parties and fundamentally i._s equal to the t

average cost per hilowatt of generation and associated transnicsion en the two syntenc.

1 Briefly, the one and o.n.e-half ti.m_e.s._b_ase r. ate is an. plied when ene party'._s rcc_er.ve d..r..op~s belo.u._..t.he. mini _m.u..n. t..o.ol rccerve percenta.re, but this has not caused the pool reserve to d. rop below the mini:vt.n. The two tir.ca base rate is applied when one or both partice' rercrves cron to the r,oir.ts that re.d.uce th,..e_.t.o.ol..r_es.e..rve tele" t.he. n..in..it.um.

At tinas these charce rates,

.~ _

exceeding th_e _bacc rate, have bc' en described as renaltics, but they can be viewed as compe.n.s.a.. tor 7 p27:ents fully justified fer the party who roccives

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revenue for increased load or as a rency-made backup for inadvertent loss of capacity.

I have handed you exc :ples of the kind: of situations a

that may exis' in the area of principal capacity adjustments and we can j).ww."

discuss these briefly., In the natter of the equit/. of ch.arring u._p to tw.o n

tince. th.e b.~a.c..c rate..,. we nicht consider the situation of tuo equally-sized systems, one of which has - say, a 23 load growth in excess of estimates.

Tnis party has, prect:::bly, then enjoyed a 2% incroace in revenue and, of

o t

- course,' has required the c:ctra P5 of capccity to supply ths.t load.

since the two cystene arc the scne size, the 25 chance of load for one party will reduce the rescree of the pool by only 10. Since the heavy load growth party's re. crve was reduced c.pproximately 23 and since the pool s

reserve has cono dxn 10, that party is cblicated to purchase 10 capacity to equalize reserve.

I:ou, if he paid only the base rate, he would have rcccived lead carryin; cnpability for 23 load grouth with only a base rate payment for 10. Tnis situation is deemed to be quite equitable in allowing the heavy load growth party to roccive increnental capacity at ts low rate; howcVer, in case reduced re erte percentage of enc party tends to jeopardire the adequacy of rescrte in the pool, it was considered proper that a rate of charge up to two tf=cs the base rate vould serte to encourage to naintain adequate roscr/e and at the scac time vould only require the deficient party to pay for required additional capacity at a rate equivalent to the average cost for capacity in the pool.

Another type of charge is a secondar/ capa.c.ity aijustment which

~-

is based upon rescrees that occur fron day to day throughout cach season.

Actually the adjust".ent is v.ade in relation to equalized reserye responni-Tai: charco rate bilitics but the chir,.c rate..i.s o.ne.-half the bare.. rate-.

Was -adopted as a r.:flection of the capacity availability frca dcy to dr.y for naintenance and cp: ration room.

In computing the,.;ccondar/ capacity v,+ N Q h M f)* O S,,V (k \\.

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}o adjustments credits and debits respectively are made to the parties.for

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any kilowatt already pu..rc.hased and co].d g;: pnincip;d capacity adjust =cnts.

Provision is made for a party that anticipates d.e.ficiency of rccerve to.

purchace fim capacity from the authorized capability of the other party in advance avoid principal capacity charges in the hi h rate levels.

C A provision is nade that as the,O.,nerati_n Cc_- n.i.t_ tee forec.c.es reserves de-clining below ninimum pool requirements, that this Conaittec will notify the w

Ad:ninistrative Cermittec and the party causing such decline shall be obli-

...s cated to remedy the deficiency in any practicabic. way even though extra-ordinary high costs are involved.

Article III provides for charing the erc,rg hoq,pcol units in propo. r.t... ion.to the r_esucctive cc.r..a. c..i..t.y-- allecations and it also.trovid.cs for sharing any econo.g ene.r.gy available on the two_nys..t. ems.

Article IV provides for purchasing capac.ity and/or energy from third.partics. Any such arrangements which arc nade v'.th third part.ies n....

oport. ting outside the State of Michigan are to be nade by the agreement of

---

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the two parties and co.stc and b.ene. fit are to be ch9.r.e.d.. e.qually.

u...,

.s Article V provides for tal:ing interconne.c..tions and int.e..r.c.h_anging capacity and/or energy by ei.ther party and a nonutility.,p3rty.

Unless other-visc agreed, such arrangenents are to be only between one party and the non *

~

utility with which it is interconnected.

Artic1c VI nrovides for the s. haring of cents for facilitics and

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operationc thereof used to interconn.ec.t. the tro n.a.rt.ies.

I:acicall-/ the

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c,.c,._s

- principle in that the total ouncrchip and o.pe.r.a_t.i.ng c.o..s.t.s of cuch inter-connections chall be ch tred ccually regardless of which con;cny's service area in the site of such facilitics.

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O Articic VII provides for the ouncrchip and operation of pool.

associated transniccion facilitics other then interconnections.

It is

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recognized that certain facilitics within one party's service area may 14.F provide a principal C. rid transmiccion., function us.eful to both part.ies.and

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this article provides that the ounership costs and operation costs thereof shall be chared equally.

Articic VIII establiches five con'11ttees whi.ch are - Administrative a. -~

Committcc, a Planning Cc:rtittee, an Operating Cc=ittec, a Fiscal Co:uittee and a public Information Co.:.ittee. The principal functions of each Co=itece are set forth in this article.

The remaining articlec, IX through XVI, cover usual provisions for such contracts dealing with cuch matte.rs as billing, modificati.o.ns, due diligence, vaivorc3 defaults, etc.

In addition to the articles, a set of " Definition of Terns" is

. ~. - - - -

included. These defi:11tions vere thought to be helpN1 in precluding an-

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biguitics of reaning in the contract.

In the contract, cach defined te =

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is underlined in order to call attention to its prescribed definith.

C, P, G,

The original contract also i._nclude.d Supplements A, 3~._ 3 11, L, li and Z vhich set forth the concral prin..ciplec and proceC.ur.ec for

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activating the contract and co=ittecs' functions. Since execution of che

~ - ~ - ~ ~ -

• Agreement in December 1%2, cone 28 amend.cnts and appendices have been a.

n

.u.t_ed.

Alno.c.t. a..l.l of these ha.ve been..a.s anticipated in the recular linc exec

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of operating the Agreement. They cover cupplements and cTangen in i.nter-connection charccc,. charing of pool units, purchases and sales of authorized capability ac voll as so=c nodifications in definitions and in' operating and planning practicen.

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PERCENT RESERVE A.K"Il 3AR~f.5 ACTUAL. RESERVES V10RE ~liie!

20RICAST (N0 ADJUSTMEMT NECESSARY)

-)HHF ACTJAL 3 ARTY X RESEU!E AC~JAL 200L ESiU!!

AC~LAL 3 ARTY '3' ;'tESE1Vi

-e o o-9% FORECAS~ED POOL RESilVI

3. 3001.lill!!!!.RfSEVE il!6!!ER n0sf. PAflifS AON

->sHF ACEJA PARTY A RESiRVE ACTUAL POOL RF.Sf_RVE.

4 Y;,Las t".ter2 b*v'*t DEFld!!iiCY ff!XI.o9% F0,9i? CASTED POOL EEE ek-e-ACTJAl 3 ARTY 3' RESERVE.

C.100. ACTUA!. IlESf.!P!f !.0rli:R TiiAiMS!!;.WED [K Gf! EATER TLI CliSE C-1 PERCENT RESERVE CASE C-2

->HHF AC" Ai )ArY

'A' Ex 9% 70RECASTID 300_

ACEAL

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un.n PERCENT RESERVE

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P00' ACTUAL RE5ER\\.l-. ESS " HAM M!N!!OM on" ".,"'3 pa.y.

9o TORECASTE) 300!. [ESERVE ""'""""'

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2% MIN iG lE0ij Pli) RESIR\\!E

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MTiV 'A' AC1 A_ RESER\\lE

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APPENDIX F Et!FFTES*TT A TO AGTCC'Tr 703 ELZ.:IC S r* ICE Z.'r:f COUE?:3 PCG1 CO::?/Jf A:~D T:C CITt 67 1967

!!OLLMID Dir.J'

?:cve-ber 15 As specified in Coction 7 of tho fe~00:ent, the =cthod for deter-miain, cr.d ivdcterminin; tha nacciatt value of :r.:tual c crGency cepccity ic as follovo:

1.

1!ollend'n rc: cree vill be deter =inad and redatemined in cecord-ance with the fomula:

R"C-L vhore:

R " !!oucad's rucerto.

C = llolland'c c.': i=>.:: not deton9trated ccpability.

Le IIoncnd'n entir.sted p;ch hourly d:: r.d for the cpp2cpricte period.

2.

Ilollcnd'a recorte reg.ont,ibilit;t vill to detomined nad redator-m17c3 in nocordanco uith thu forn.la:

O. % - 0.15L C '

3 1m = "

7 4 0.15L d

vhore:

RH = 1:ollend'n re 2?rv recponnibility.

01 " !!cxirsa not d3.:en:t:t.ted crisility of Holla".d'o 1 crc:st unit.

C2 = linxira.tm nat d:=0nctrated ct.p:bility of Ilonand's cecond larc: t unit.

L = 11onend'n esticated p: /. hmirly 0=and for the cypropricta period.

(Sara es in 1 tbeve.)

3 The ntitual t,ccrcency cc :: city chcll t.: detemined cad redeter-nined by c:thtrnetin; llolland' r rai-to responsibility (DR ca cespu.cd in 2 above) frca l'ollnad'n reservo (:i r,c coegut:C in 1 tbuve). The value ot-tutual c:acrcency cap;0ity to bc utilinad for the cppropi!cte periori oncli be 1 minded to the nearcot nogc.rcts.

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APPENDIX G b

l EXHIBIT "A"

Page 1 of 2 l

Case No. U-2291 RULES GOVERNI;tG THE EX'EITSION OF sit'GLE-Pu3SE ELEC-TRIC SERVICE I:T AREAS SERVED BY T..'O OR ": ORE UTILITIES 1.

For the purpose of those rules i

(a) the word " utility" shall include both a private i

utility and a rural electric cooperative; 00) the term " distribution facilitics" shall include i

both single-phase and three-phase service and shall not include service drops; (c)

" distances" shall be determined by direct measure-ment from the closcst point of a utility's c::isting distribution facilities to the custonor's meter location and shall not be determined by the circuit feet involved in any extension; (d) the word " customer" shall mean the buildings and facilitics served.

2.

Existing customers shall not transfer from one utility to another.

3.

Prospective customers for single-phase service located within 300 feet of the distribution facilitics of two or more utilitics shall have the service of their choice.

4.

Prospective customers for single-phase service located at a distance greater than 300 feet and within 2,640 feet from the distribution facilitics of two or more utilitics shall be served by the closest utility.

5.

Prospect.ve customers for singic-phase service located more than 2,640 foot from the distribution facilitics of any utility shall have the service of their choice subject to the provisions of Rule Eo, 6 4

4 a

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EXHIBIT "A" Page 2 of 2 6

The extension of single-phase distribution facilitics, except as provided ir. Rules Fo. 3 and No. 4, where such extension will be located within one mile of another utility's distri-bution facilit.es, shall not be made by a utility without first giving the Commission and any affected utility 10 days' notice of its int:ntion by filing a map showing the location of the proposed r.eu distribucion facilities, the location of the prospecti4e customers and the location of the facilities of any other ncility in the area.

If no objections to the proposed erkension of single-phase distribution facilities are roccived within the aforesaid 10-day notice period by the Commission, the utility may proc 0cd to construct said facilitics.

~

7 The first utilicy serving a customer in accordance with these rules shall be entitled so serve the entire electric icad on the promises of that custcmcr even though another utility is closer to a portion of the customer's lead.

D.

A utility may waive its rights to serve a customer or group of customers provided that another utility is willing and Eble to provide the required service and the Commission is notified and has no cbjections.

9.

Nothing in these rules shall prohibit a utility or a customer from applying to the Commission for relief from the operation of these rules or prevent the Commission frem granting such relief if it finds such action to be in the public interest.

10.

Bothing contained in these rules shall be construed to circum-vent the requirements of Act 69, P.A.

1929, or to authorize a utility to extend its service into a municipality then being served by another utility without complying with the provisions of the before-mentioned Act 69.

O APPENDIX n (To Ee Supplied)

O