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GROUNDWATER HYDROLOGY

El Capitan Source Water System

R. M. BRACKBILL SHELL OIL CO. Downloaded from http://onepetro.org/JPT/article-pdf/16/12/1351/2218694/spe-912-pa.pdf by guest on 28 September 2021 MEMBER AIME MIDLAND, 7EX. SHELL PIPE LiNE CORP. J. C. GAINES HOUSTON, 7EX,

Abstract County, led [o Shell’s investigation of additional water The talents of pipeline and production engineers can sources as an allied investment opportunity. Allied op- be coordinated to create opportunities for diversified iit: portunities might be differentiated from diversification il, restments. This has been demonstrated by the efforts of that it is management’s desire to find additional invest- Shell Oil Co. and Shell Pipe Line through the construe= ment programs through further util ization of availahlc tion of source water system, which serves talent and experience, I)lany Pcrt)lian Basiiz secottdury recovery injection pro- A review of local water sources for Shell’s Ector gf.~,n.yt County water injection opemtions during 19fJ() indicated Ihc project was conceived during 1960 after the need that the avaihtble sources might prove irmdequate in fur a large water supply was recognized. A study of lo- many areas if they were developed on a wsiksteral lease basis. It appeared that fresh water sources would have cal water-bearing foswations, suggested that these sources might be inadequate to serve projected secondary recov- to be exploited beyorid the limits of some of the oil ery pro.r.vams and still provide suflicietrt water for resi- fields to assure an adequate water supply. Since other dential, farming and iudustria! requirements. The Capi- operators undoubtedly experienced similar problems, it tan reef cotnplex was selected frw the supply because the presented an excellent opportunity for a water supplY extensive aquifer yield,r brackish sulfide water suitable service. Two alternate water sources given considerateion jor injection, were the Capitttn reef complex in Winkler County, a The initial project when completed will require a capi- prolific aquifer which had yielded several billion barrels of brackish sulfide water with little or no drawdown, tal expenditure of an esfimated $10 mil!ion. lt will be capable of delivering some 2.8 billion bbl of water af a and the Ogaltdla formation in Gaines County. a shallow. s rote of 600,000 BID from 18 wells auproxintafely 5,000 fresh aquifer, Further investigations rcvettled that one major oil pro- ft deep. Thesvater \;ill be pumped’ ~rrough seize 135 tniles oj line ranging in size downward from 36 in. at the ducer had already laid a water system from the Capitan 5,000-hp pump station. Additional capucity up to 1,000, - reef to supply its Ector and Crane counties field injec- 000 B!D can be obtained with only additional source tion requirements, that another operrttor hitd purchased welts and pu171ps being required, The water will be sup- water rights with plans to bring Capitan reef water to its plied through a closed system free of air to 28 ter- projects in Ector County, and that operators of other minals, each with meters for cus[ody transfer. The well.v Ector County projects had purchased the Odessa city ex- ant! pump station are equipped with gas engines ancl cess water” capacity and the Odessa butadiene plani waste the F;ece.&ary auxiliary equ~pment to permit automated water. operafiof t. Several oil producers had substantial operations in Ec- While nearly four years have been required from in- tor County, while Shell’s interests were dispersed with its major operations in the TXL field area, where water re- CL>@Oil fo delivery, less than a“year was required for de- sign, development and construction, The greatest time ‘quirements were neither immediate nor relatively large, It appeared certain that Shell operations would be served and effort were required for contract negotiations for water rights. for right of way, and with the water pur- either incidental to the above systems or through local water development. Consequently, a water source service chrrsers. was not actively pursued. Through cent act in engineer- Introdttclion “ ing committee work in late 1961, Shell was advise~i that at least one of the other operators with. water rights could “The advent of expanding secondary recovei opera- not construct a pipeline to deliver water from’ the Wink- tions, together with the growing demand for water util- Ier County reef into Eetor County. The reason given “was ized in the industrial expansion and agriculture in Ector that a group of ranchers controlled sufficient lands be- “ Original manuscript Iwsivcxt In Society of Petrnlewn Engineers otllce tween the water source and the Ector County projects Aug. 3. 1964. Revised manuscrirst received Nov. 2, 1964. Paper we. and that they had made exorbitant demands for water sented at !l!3thAnnual SPE Fail MeetIns heId in Houston, Oct. 11.14, 1964. transmission rights across those lands. ~.-, d“ -

It soon became obvicw that the company which could erately mineralized water not suited for irrigation or hu- obtain right-of-way out of Wlnkler County could prob- man consumptio~ is contained in the Permian reef com- ably organize a water source system to serve most opera- plex of the upper Guadalupian series that parallels the tors in the Ector County area. It was then that Shell PIpc western edge of the central basin platform @ig. 1). Line was contacted with the idea of utilizhrg second line Availability of water in the proximity of the reef was lay rights along its existing oil lines to cross the lands first recognized in 1927, shortly after discovery of the controlled by the ranchers. Shell Oil and Shell Pipe Line Hendrick oil field in western Winkler County, Tex. The soon agreed as to the feasibility of constructing a water majority of the field wells produced large quantities of supply system and immediately obtained water rights. water without any significant indication of decline in ca- While the second line rights were available, the route was pacity. When the wells ceased to flow, submersible not the shortest or most economical, ‘---’1 pumps lifted thousands of barrels of water per day with During early 1962, at a meeting of all potential water water cuts approaching 100 per cent, From thk perform- users, a steering committee composed of major water ance it was apparent that the oil accumulation was in injection. projects was organized to work out a“ solution communication with an extremely large aquifer. The pro- to the procurement of source water for the waterflood op- duced water was relatively fresh, ranging from less than 5,000 to near[y 20,000 ppm total dissolved solids. erations in Andrews, Crane and Ector counties, with Downloaded from http://onepetro.org/JPT/article-pdf/16/12/1351/2218694/spe-912-pa.pdf by guest on 28 September 2021 the object of selecting a company to provide the needed It has been postulated ‘that in late Guadalupian time service,’ The committee, through its engineering group, marine environments were restricted by the growth of determined locations to be served, the yearly and total reefs around the . in water requirements, approved the Capitan reef complex West is the focal point of the Permian reef corn- as having ample water of acceptable quality, and pre- plex exposure, where about 40 miles of the Capitan reef, pared bid specifications for the service. The bid included or about one-tenth of the total length, is exposed in the the total cost of water delivered to specified locations, Gw&dalupe mountains. To the northeast of the scenic with mil.,mum guarantees of usage, The ultimate water peak the reef is found at shallow depths, A well-known volume amounted to 2.8 billion bbl, with peak daily tourist attraction, the Carlsbxd Gverns, is contained in rates of 600,000 bbl. When the bids were opened in the upper portion of the reef where ground waters have July, 1962, it became clear that the reef water source formed large chambers. Not too distant from Carlsbad could prObdbly not be delivered to most of Andrews appears to be the principal recharge area. Salt water that County at a price competitive with fresh water produced was contained in the reef when it was deposited has been from the Ogilalla aquifer in that area. Shelf’s bid for a systematically flushed by precipitation entering the for- 70-per cent annual guarantee was based on laying a sys- mation. tem using second line rights and right-of-way options The geology of the sediments occurring on the eastern purchased on the remainder of the Winkler County margin of the Delaware basin in Winkler County is es- route and on developing water from lands it had pur- sentially the same as observed in the outcrop. These reefs chased on the reef. This proposal was made contingent are also present in the supply area, but because of deep- on Shell’s being able to utilize its additional line rights. seated faulting greater relief was present during most of Shell eventually worked out an agreement with the combine of ranchers, whereby Shell acquired additional water rights and the right to lay pipelines from these ranches, This contract was executed during May, 1963, and allowed the water field to be developed considerably closer to the users and reduced the amount of pipe re- quired. During the period of negotiation with the rancher 1, I 2“’”’”$) I combine, firm nominations for water requirements were solicited from all the major water users. The fieldwide nominations by the largest operators in each field indi- cated a need for 28 terminals rather than the 9 in the original bid specifications. In this connection, Shell Oil Co.% staff completed an essentially independent time, rate and total volume study for the entire system for ii””o !’%..””r~ confirmation of the water nomination data and consid- eration by Shell Pipe Line. The facilities being installed consist of 18 wells drilled into the Capitan reef in Winkler County, approximately . 135 miles of pipelines, 6- through 36-in. in diameter, metering facilities at each delivery point and engine-driven pumping equipment totaling 8,400 bhp. All wells and vessels are gas blanketed to prevent air-water contact; and the water is delivered to the purchasers’ tankage or ------i. pump suction at. pressures not less than 25 psi. %,. .?C xt:G --’-f’’’’’7”::’’”::.i# ‘-% ,,. /.s % Geology ‘\ [ An investigation indicated that the most promising ‘ vi.,,, r wk. i’ ,< ‘. prospect for water to supply the Ector County second- ary recovery projects was in the western part of the ad-, Fig. l—(kotrtdized gcolotirul setting of Permism reef joining Wirskler County, Here a vast. quantity of inod- cmoplext ‘l’exitsmrd.NcwMcsieo. Permian time and the reefs are more nearly stacked iveiy replenished from the Capitan reef outcrops to the than observed elsewhere. As a result, the reefs that have west of the Artesia area. This is aiso pertinent to the a relief of about 3,300 ft only cover a lateral distance prediction of future decreases in fluid level, since even of 6 miles, The crest of the shallowest reef, the Tansill, if the proposed withdrawal rates are increased signitl- is encountered at about 3,200 ft in west central Winkler cantly beyond the forecast rates, the fluid levels should County. Although this portion of the shelf margin buiid- not continue to decline after 11 years. They would up is a potential source of large quantities of water, it probabiy level off due to the replenishment from the is the most distant from consumers. The Seven Rivers outcrops being felt as steady-state influx conditions are reef, found 200 to 300 ft deeper but nearer to the reached. terminals, has been selected for the development zone. Due to the high ~rmeability of 6 darcies estimated Most of the welis wili be completed in this reef but, pro- for the main reef mass and the rapid moveout of pres- gressing shelfward, backreef sediments adjacent to the sure transients, relatively small advantage would be reef core also possess porosity and permeability and some gained by striving for maximum well spacing. Calcula- of the source wells wili be completed in this zone and tions indicate that the difference in required pressure the deeper G myburg reef, Preliminary testing suggests drop between spreading the required welis over a 2-mile that the entire reef mass might be in pressure communi- square or a 6-mile square would be less than 10 per cent.

cation, and -wtisfactory welis can be developed at any The 160-acre well spacing appears to be suticient to Downloaded from http://onepetro.org/JPT/article-pdf/16/12/1351/2218694/spe-912-pa.pdf by guest on 28 September 2021 location in the immediate vicinity of the present water minimize weii interference. It should be noted that the supply wells. In the exposure multiple reefs of vuggy maximum drawdown wiil not be reached until after 12 iimestone have been delineated. years, whereas peak demands wiil be reached in the fourth and fifth years and then gradually decrease. Water Soim2e Evaluation Therefore, if it does become necessary to lower the The reef complex wiii provide an adequate water pumps in later years, the peak rates of production will source for secondary recovery projects in the vicinity of have already been met and the equipment may be Ector County, Cumulative water production of the Per- available from supply wells which are no iongcr needed. mian reef complex from wells iocated in Winkler, Ward and northern Pecos counties is estimated to be in Water Source Development excess of 8 billion bbl. Most of the withdrawals to date The drilling and completion program for the source h~ve been produced from the less-permeable back-reef wells dhlers little from that of a 5,000-ft oil well. The sediments in the associated limestones. Resuits of 13%-in. production casing cemented at 1,000 .ft was drawdown tests and production performances suggest provided to accommodate the lift equipment. Because that these formations are in communication with the of the shaft-driven pump it was necessary to require a massive reef aquifer which is being continually re- straight hoie be drilled, with a maximum deviation of charged at a significant rate. The relatively small drop in 1° at 1,000 ft. A 9%-in, liner was cemented at the top hydraulic head that has occurred after the tremendous of the reef, encountered at approximately 3,200 ft. An amount of production is considered conclusive evi- W4-in, hole drilled to total depth of 5,000 ft with dence of an assured water source for our project. aerated water provided the maximum wellbore radhrs The reef water is only moderately mineralized along with a minimum of cuttings contamination to permit the east side of the platform, and eastward across the unrestricted inflow. Midiand basin the water is very highly mineralized. A gamma ray-sonic “log was run in each well for This suggests that there is significant water movement correlation’ purposes. The well was then tested to deter- in Texas and that it must be along the west and south mine static and pumping fluid levels. A 20,000-gal sides of the Central basin piatform, Higher static fluid acid treatment was performed and the weil retested. Re- ievels have been observed in Ward County source wells sults of these tests were used to determine the setting which could be indicative that some influx is also oc- depth and capacity of the pump to be run i]! each indi- curring from outcrops in the Giass mountains, about vidual well. 100 miies south of the Hendrick area, as well as in New It will be necessary to drill a minimum of 18 wells Mexico. during the first three years of operation. The final de- The amount of fluid that can be produced from a termination of the number of wells depends upon the given well appears to be a function of the amount of productivity of subsequent welis and the expansion of the pay open to production and the design of the lift equip- water system. ment. Individual wells have been tested over 60,000 The depth of lift is a function of time and withdraw- BWPD. Initial static fluid levels varied from 175 to als. Although the maximum lift depth of approximate- 225 ft. ly 460 ft wiii not occur until about 1975, the peak wa- Unsteady-state water influx calculations indicate that. ter requirement should be reached in 1967, and water present fluid ievels will be lowered by not more than demand wilt gradually decrease for the remainder Of 380 ft as a tesult of demands of the secondary recovery the project. projects. Shaft-driven turbine pumps were’ selected for this The resuhs of steady-state influx from the Artesia project. These water-lubricated pumps have 12-in., ” 8- area and transient time calculations indicate that the stage bowl assemblies of 316 stainiess steel, 8-in. inter- current steady-state water influx into the Hendrick reef nally plastic-coated column pipe, i 7/16-in. monel shaft- area is some 430,000 BWPD. The time-required to reach ing and glass-impregnated teflon bearings in Ni-Resist Type steady-state conditions at. the Artesia outcrop is indicated I spiders. These pumps provide 33,800 B/D/well from to be 11 years, although the initial effects of the tran- 345 ft with a surface discharge pressure of 50 psig, This sient begin to be felt at the outcrop in approximately discharge pressure eliminates a booster pump at the main four years. Thus, while a considerable time lag is in- pipeline pump station. The prime movers are, 150-hp gas volved, it appears that the fluid withdrawals from the engines. equipped with admiralty bronze heat exchangers Hendrick area in Winkler County are now being effect- installed in the wells’ flowiines. . . . . IIECEMBER-, 196.4- ‘. .K1.$s

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Design and Planning rious twntract companies performing the many construc- tion and development activities in the field. Much has been said about what is a “good design”, and the definition one may receive from the engineer, Water (luaiity and Corrosion Controi the operating personnel, and the investor may not necessarily be compatible in view of each group’s inter- The Capitan reef water now being produced contains approximately 10,000 ppm dissolved solids and about ests. Often the engineer wants the facility containing 175 ppm H2S. This water is satisfactory for injection the utmost in technictd exce[ience; the operator of the without treating, if it is delivered as produced. It is pos- faciiity, naturaliy, desires the one which accomplishes sible that the composition of the reef water will vary as the objective with a minimum of trouble, with the ten- a result of water removal from the producing forma- dency at times for the investor’s requirement of a profit tion, or by the effects of temperature and pressure becoming a secondary issue. Much as we would like changes as it is produced, to have designed and installed these facilities to contain The basic problems encountered which were peculiar engineering marvels which would o~rate forever with no to this project were those created by the highly corro- inconveniences to the operating groups, our primary sive characteristics of the water and the necessity of consideration has been to accomplish our objective to building an air-free or’ closed system as required by the the greatest “economic interest of our investors. contractual obligation to the water buyers. The corro- As the basic design of all fluid pipeline systems csm be sion and water quality control program is designed pri- Downloaded from http://onepetro.org/JPT/article-pdf/16/12/1351/2218694/spe-912-pa.pdf by guest on 28 September 2021 expressed in formulas, Sheil has developed computer marily to detect and mitigate against contaminants in- programs which are utilized to perform the mass of cal- troduced by the pipeline system. culations formerly done by engineers and necessary to The only anticipated contaminants of any conse- permit selection of the system which wiil provide the quence are oxygen introduction and pieces of defective greatest ret urn on the investment. By utilizing the com- internal coating or lining being entrained in the water. puter, engineers have been able to explore many solu- Removal of solids is accomplished by installing strainers tions which would be impossible if calculations were at each delivery point. made manwrliy. Variations of these computer programs Introduction of oxygen into the system would not only have been developed to utiiize basic known data which tend to accelerate corrosion, but could possibiy generate may vary with different propositions; however, the basic corrosive products which might impair the quality of the input data which were supplied are as follows: (1) hy- water for waterflood use. The presence of oxygen in this draulic formula to calculate pressure drop in lines for water is determined by the chemical analysis of oxy- fluid to be handled; (2) characteristic data of fluid to be gen deniand and by electrolytic cells or oxygen meters handled; (3) throughput quantities expressed M B/D for which measure the dissolved oxygen content, Weighed each year of service: (4) inside diameter of pipe; (5) corrosion coupons are used to detect the occurrence of profile data of terrain to be traversed; (6) unit invest- accelerated corrosion. Millipore filters are used to detect ment costs, (a) $/ft for pipe installed,, (b) $/hp for any increase of solid corrosion products in the water. operating hp, (c) $/fixed for special feat ares, tankage This routine employment of these oxygen-sensing de- communications, etc.; (7) operating expense schedule, vices and techniques at selected locations along the pipe- (a] $/n~ile for maintenance of lines, (b) $/hp/ year for line system shouid detect and avoid water contamination. operating hp. (c) $/yew for personnel, automotive, Other tests for water qt!ality controi which have been overhead, etc.; (8) tax depreciation rates; [9) ad va- considered are those for sulfate reducing bacteria, tur- lorem and income tax rates: (10) discount rate for pre- bidity, dissolved iron and iron sulfide. sent value calculations; (11) end of life salvage and valuation; and (12) tariff ($/bbl) or rate of return. Source well casing is externally protected by cement. T!te casing-tubing annulus is sealed at the surface and a Calculated data for each incremented input which gas blanket maintained. The source well casing is not may bc read from the computer run sheets are as fol- coated internally. lows: (1) total investment; (2) operating horscpowe~ (3) A study was conducted to determine the economics opemting pressures; (4) revenue, operating costs, tax of casing protection, and the possibilities of successfully credits,. and amounts of ad valorem and income taxes; obtaining this protection. The following conclusions (5) profit before and after taxes; (6) cash generation; were made: (7) payou~ (8) present value of investment, cash gen- 1. There is doubt that coating applied to the casing eration, profits; and (9) rate of return or tariff. would remain intact throughout the drilling operations, Utilization of the computer has not oofy provided the 2. The cost of various internai coatings increases information necessary to evaluate the economic feasibil- source well costs as much as 14 per cent. ity of a proposition such as Shell’s El Capitan system, 3, Experience indicates that, where the casing is pro- but has also provided the basic design information with tected externally by a cement sheath and internally by regard to correct line sizes and horsepower requirements. an oil fiim, an inhibitor film, or a gas blanket, corrosion By determining this basic information in the initial is greatiy reduced. phases of the project, the engineer may concentrate on 4, Laboratory results from weight loss coupons ex- solving the problems peculiar to the system to be in- posed smaerobically in reef water indicate a uniform cor- stalled and on the pianning necessary for the efficient rosion rate insufficient to penetrate the casing during the completion of the over-all project. .’ life of the project. Much has been said and. numerous articles have been 5, Even if penetration of the casing should occur, over writteii regarding job planningi On jobs” of “the xmtin’e of 10 leaks cati be repaired by sqileeze cementing for a total this water supplY system, a project manager is assigned cost equal to that of the lowest priced coating. the responsibility of not oniy assimilating the contribu- Selection of Materiais, tions of the Shell Pipe Lhte aod Shell Qii specialists into the design and execution phases of the project, but also The planned progra~ of corrosion mitigation and OXY in coordinating and scheduling the activities of the va- gen exclusion should minimize the corrosion” damage to

1ss4 $.QURNA.L OF PETROLSiJM T13CHNOL0GY, .,. . the facilities in this system; however, damage can he ex- movement after being placed in service. pected if the proper corrosion resistant materials are not Cement asbestos pipe was used in the water tield gath- used, or if the conventional steel materials are used and ering system. This pipe was joined by utilizing cement as- not protected. bestos couplings with the water seal dependent on a non- The cost of pipe in a pipeline system not only repre- Ioad-beariisg rubber gasket. Cement asbestos is impervi- sents approximately 75 per cent of the total initial in- ous to corrosive action of water, and when installed cor- vestment, but is also the most costly item to maintain if rectly, will require minimum maintenance, As in the case corrosion is experienced. Steel pipe, lined with mortar or of the concrete cylinder pipe, proper beddhg and com- coal tar enamel, concrete cylinder, and concrete asbestos paction of the backffll was essential to prevent pipe pipe were used with the selection being made primarily movement and joint failure after the line was placed in on an economic basis, Failures have occurred” on all service. four types of pipe in similar service, with these failures generally being attributed to, faulty workmanship in in- Operating Features stallation, The lines installed in Shell’s )31 Capitan sys- tem consiit of pipe types and sizes as shown in Table 1, The movement of water through a closed system or Mortar-lined steel pipe was used for the Ector County air-free system in lieu of utilizing large surge tankage at distribution lines. This pipe is internally lined by cen- both the delivering and receiving terminals, as is the con. trifugally spinning a %-in, Portland cement-mortar mix, ventional practice in water handling, required facilities The remainder of the dry mix consists of either raw or having a high degree of operational control, The unin- Downloaded from http://onepetro.org/JPT/article-pdf/16/12/1351/2218694/spe-912-pa.pdf by guest on 28 September 2021 calcined natural pozzdasw, or granulated blast furnace terrupted movement ‘of water from 18 wells dfrectiy to slag and glass sand (silica flour) ground so that 100 per a S,000-bhp booster station, then through 135 miles of cent will pass a No. 200 sieve. The silica flour content line to some 50 waterflood units having individual de- was limited to a maximum of 20 per cent. mands varying from 1,000 to 150,000 B/D, without lhe After lining and exte nally coating with coal-tar use of large storage tankage, may at first appear in- enamel, the line was installed by butt weldbrg and utiliz- surmountable. It is felt, however, that the science of in- ing an asbestos gasket at each joint. Extreme care was strumentation has progressed to the point that the exercised to ensure a tight joint to prevent water contact closed-system facility in this case can be more economi- with the steel. cally provided, and also retain the required reliability The initial 20 miles of the mainline is of 36-in. spiral foruninterrupted service (Fig. 2), weld 0,281-in. and 0.250-in. wall. grade X-42 steel pipe, Before any type of automation and instrumentation internally and externally coated with coal tar enamel and could be planned, the decision on the type of prime joined by butt welding, The lining is 3/32-in. thick mover to be used and the degree of reliability for unin- and is applied over a sandblasted and primed surface by terrupted service had to be ascertained. Upon investi- centrifugal spinning. Each joint was field coated both gating the facilities installed in the waterflood units, it internally and externally after the weld had been com- was revealed that a part of the units would have nomi- pleted. The internal coating operation limited the mini- nal surge tankage while others would take suction di- mum pipe size used to that in which a man could work. rectly from. the distribution line and would be shut After the field joints were completed, the coating and down on a failure to receive water. Further, tbe water- lining were inspected by a holiday detector, and the net- flood units would be operated unattended and manual essary repairs made, restarting would be required when shutdowns occurred. The balance of the main distribution line consists of It was concluded that a temporary slowdown in line 45 miles of concrete cylinder pipe in’diameters ranging rates could be permitted while a complete loss of from 16through 36in. This pipe wasmanufactured by us- throughput, even if for short durations, would shut down ing light-gauge steel cylinders, reinforced with roa all units and couid not be tolerated. Admittedly, the elec- wrapped un~.c tension ta give added strength. The in- tric motor can be more economical] y automated and is terior is mortar lined while the exterior is coated with a more reliable prime mover than the gas engine if its concrete. The pipe joints are of the bell and spigot type, source of energy is not interrupted. It has been Shell’s grooved to receive a rubber gasket. The joints are of.the experience that the engine.driven station will experience self-centering type so that, on closure, the gasket will practically no complete shutdown, whi[e the shutdown not support the pipe, but will be suitably compressed to resulting from power supply failure on the electric-drive effect a watertight seal. Cement grout was placed in station is not infrequent. Actual costs of both electric each joint to prevent water contact with the steel in the and gas equipment, and power and fuel rates for the bell and spigot area. On pipe sizes Iess”than 20-in, di- operating horsepower were obtained, and with the use ameter through which a man cannot traverse, an as- of the computer, the two types of prime movers were phaltic ring, which may be placed prior to closure; was compared. Thk study revealed that the gas engine was used in lieu of the internal grout. Special attention was the more economical prime mover for this applic~tion, given to the bedding and compaction of the backfill Accordingly, 800-hp engines were specified to drive the when installing concrete cylinder pipe to prevent its centrifugal pumps for the main booster station and 150- hp engines to power the shaft-driven pumps for each well unit. TABLE I Facilities’ have been provided “to permit unattended op- Wate:-4$:o~herIns System: Cement asbestos eration with personnel required for servicing equipment With Operating pmssums lam than 1S0 PSI during the daylight shift, Twenty-four-hour observation Dlstr~~onn Systam, ” of the system will be maintained .by the Shell’ Pipe Line!s Cement lined sfea[ ‘Wl;h “i~eraflng weswro$ dispatching personnel located at McCamey, Tex. ematerthan 150 ml AI1 engines are equipped with the conventional safety 16.36 In. Concrete cylinder With operating pressures devices, have automatic lube oil regulators, and utilize lass than 175 ml heat exchanger cooling, The 150-hp well engines may 36 in. With ekter than 175 PSI Coal far iinod sfeol operating pmwre be automatically started from either the McCamey office —,. ,. .

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1 A Fhz. 2—El Copitnn water line.

or El Capitan station and are speed-controlled by line more. ‘reliability, but also eliminates the surge pressure pressures. conditions which would be experienced with a fast-acting The number of wells operated at a given throughput control system. rate are chosen so the engines will operate at 850 rpm. Should one well shut down or the required throughput Summary rate” increase, the operating well engines automatically The initial water deliveries to purchasers for secPndary speed up to provide the additional water, The speed con- recovery operations in the Permian Basin climaxed an trol is limited from 700 to 1,000 rpm. unusual investment opport mity for the shareholders of The 800-hp El Capitan station pump units are Shell. This joint endeavor of the Pipe Line and Produc- equipped with automatic starting and speed control so tion organizations was made possible only with the com- the throughput rates may be varied as necessary to en- plete coordination of technical, legal, financial, operat- sure a 25-psi minimum delivery pressure to all water- ing and land personnel of the two organizations, Whh- flood terminals. Four pressure transmitters are located out full utilization of the skills and experience of each along the delivery lines to monitor and transmit the de- group, this system could not have been completed to livery pressures to the station control system, The trans- permit the most economical source of water to the Ec- mitter recording the lowest pressure controls the tor County oil producers. throughput by effecting the necessary speed variation of the mainline pumps to either raise or lower the delivery Acknowledgments rate. The stand-by mainline pump unit is fully automated to come on the line should one of the operating units The authors wish to express appreciation to the engi- shut down or if the required “throughput exceeds the ca- neering staff of the Midland Production Div., Shell Oil pacity of the pump units in operation at their maximum Co,, and to the technical specialists of the Shell Pipe speed, The conventional low-suction and high-discharge Line Corp. for their assistance in preparing this paper. presspre control system is incorporated to prevent com- plete loss, of throughput when a large variation in re- Reference , quirements is experienced. 1.Newell, N. D., Ri@y, J. K., Fisher, A c., WhiternamA. J., ‘- The only tankage installed “in - this system consists Hickox, J. E; and Bmdley,-J. S.: % Pernn’an‘Rml ComP~= of a 250-bbl suction surge tank with automatic level con- o! the Guoaldupe Mountafns Region, Texas and New Mem”eo. Freeman and Co,,San Franciwo (1953). ** trols and gas blanket ing equipment. This tank provides additional water equal to approximate y 10 minutes op- IIDITOR’S NOTE: PICTURES AND BIOORAPHICAL SKETCHES eration of one well. This stand-by water supply not only OF R, M. BRACKFtILL AND 1. C. GAINES APPEAR ON PAGE permits the use of slower acting control devices having 1389.

1%s6, JO1’RXAI, OF PE;FROLFWM TI!cIINO I.OCY —. ,.- .- . . . . .