JPRS ID: 8596 USSR REPORT RESOURCES

• Document Type: CREST
• Collection: JPRS
• Document Number (FOIA) /ESDN (CREST): CIA-RDP82-00850R000100070041-8
• Release Decision: RIF
• Original Classification: U
• Document Page Count: 50
• Document Creation Date: November 1, 2016
• Sequence Number: 41
• Content Type: REPORTS

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3i JULY i9?9 CFOUO i9179~ i 0~ i
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JPRS L/8596
31 July 1979
USSR Re ort
p -
RESOURCES
CFOUO 19/79)
FBIS FOREIGN BROADCAST INFORMATION SE~VICE
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- JPRS L/8596
~ 31 Ju1.y 19 79
?
USSR REPORT
' R~souac~s
_ /
_ (FOUO i9/79) -
~
- CON7~NTS PAGE _
FUELS AND RELATED EQUIP~tENT
Sw.ivel Device f or Casing Oil Wells Described `
(V.V. Vaulin, et al.; BURENIYE, Apr 79) 1
' Mehhod for Formation-Testing of Cased Wells Described
(V.D. Banchenko, et al.; BUItENIYE, Apr 79) 8
, Recent Progress in Building Surgut-Polotsk Pi.peline Recounted
(A.A. Plotkin; STROITEL'STVO TRUBOPROVODOV, May 79) 13
Precast Concrete Items Heat-Treated in Natural-Gas Combustian `
Products -
(STROITEL'STVO TRUBOPROVODOV, May 79) 16
West Siberian Pipeline Construction Speeded by Reorganization
~ (V.V. Postnikov, A.A. Paramonov; STROITEL'STVO
TRUBOPROVODOV, May 79) 18
Oil, Gas, Water Collection and Preparation Discussed
(G.S. Lutoshkin; SBOR I PODGOTOVKA NEFTI, GAZA I VODY,
1979) 25
Well-Brilling Fundamentals Discussed -
(Yu. I. Volodin; OSNOVY BURENIYA, 197$) 30
Coal Concentration Development in Ukraine
(P.N. Ivanov; UGOL' UKRAINY, May 79) 33
MINERALS
PresEnt State and Pros~ects af Introducing Compacted and
Underground I.Eaching of Ores
(A.S. Poplaukhin, et a?.; TSVETNYYE METALLY, No 3, 1979). 4Q
- a- [III - USS R- 37 FOUO]
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I~UrLS ANU I2CLATCD LQUIPMCNT -
UDC 622.245.123:622.245.6
5WiVLL DEVICr E012 CASING OIL WELLS DESCRIBED '
' Moscow BURFNIYC in Russian No 4, Apr 79 signed to press 15 Aug ?8 pp 24-27
[Article by V. V. Vaulin, V. B. Nazarov and G. V. Golovanov of Gro2neft'
[Groznyy Association of the Petroleum Industry] and SevkavNIPIneft' (North
Caucasus Scientific-Research an3 Design Institute for the Petroleum Indus-
try]: "Casing off Wells with Liners and Casing String Sections with the
Use of a Swiveling 5uspension Device"]
[Text] A method for casing wells with liners and also for lowering casing
string in sections has found wide application in recent years in many pe-
troleum-producing regions of the Soviet Union where deep drilling is going
on with the use of wells of multiple-string design. The Grozneft' associ-
ation calls for, in almost every well design, the loweri.ng of one or two
liners and the overwhelming majority of casing strings are being lowered
in sections. Because of this, questions of sectional lowering acquire
special urgency.
Since the technologies for lowering and cementing sections of casing
string and of liners are basically identical, in the following deseript~on
the concept "sections of casing string" relates al~o to liners in equal _
degrer The installation of a section of a string that rests on the bot-
~ tom hole is prohibited by existing instructions [1], to avoid bending and
violation of the string's integrity. Casing string sections should be
suspended in the well by means of one of the following well-known methods:
suspension on wedges, suspension on a support, or suspension on a cement
rock [2l.
In Grozneft', as in other organizations that are drilling 9eeply, the
method of suspending casing string sections on a cement rock has found
widest application.
The main advantages of this method are the potential for suspending a sec-
tion of the string in any part of a cased or uncased well bore and simpli-
city of design of the string hanger and ths suspension technology.
At present, diverse designs for string hangers for suspending sections on
a cement rock are being used, one of which is shown in figure 1.
1
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F'igure 1. Denign Variant for a 5tring Hanger on a Cement
Rack. � '
r
1. C~,?iLrol hulls. 7. Coupler of threaded ! ~
2. Cut stud bolts. string diaconnectior. ,,,o
= 3, ~lushing ori.fice. 8. Lower suspension part of ~
4. 5leeve. two-section dieconnector J =
Plug� .
5. Cover.
6. Nipple of threaded 9. Casing pipe
, f_
strin disconnector. 6
f
Thc devices indicated have common deficiencies.
i. The necessity for leaving the drill pipe, on whieh ,
the section of casing string is lowered, in a fixed posi- .a
- tion throughout the whole period of the OZTs [waiting for '
the cement to hardenJ, and, where there is large section i'~
weight and small annular clearance,when reciprocation nf ^ ~
the string is not permissible because of the possibility
of serious complications, also throughout the whole pre-
ccdin~ OZTs period. This can lead to sticking of the
drill pipe by the cement solution that is setting and is
not driven out from the dead zone where the drill string
is stationary, and also to "adhesioii" of the drill string at the intervals
of deposition of the permeable rocks.
2. The necessity for discharge of a ball for cutting off the suspended
upper string of the disconnector F~lug and a second ball for opening the
flushing orifices in the string hanger. This occasions instability of the
process and the dependence of it upon chance (the ball getting caught,
stoppage of the cementing units~ and so on).
3. Difficulties during disconnection of the drill pipe from the easing; and
jamming af the left-handed thread, caused by the complexity of removal of
the load from the left-~handed thread of the threaded string disconnector
at the moment of turning away.
Taking the deficien~~es of existing designs into account, devices are be-
- ing developed that will permit casing string sections to be cemented with-
out resting upon the bottom hole, rotation of the drill pipe string during
the OZTs, and, in so doing, flushing of the well above the upper part af _
. the section [2-5].
In GroznePt', work on the creation of similar deviees has been going on
since the end of the 1960's. A group of Grozneft' workers and SevkavNIPI-
neft' staff workers has developed a design for a swiveling suspension
VPU-1 device with a threaded string disconnector (figure 2)�
This device consists ot" a bcdy 6 with an adapter 1 joined to it and a
case 9, a core 8, and a thrust bearing 7, and a movable slceve 10 that
covers a radial flushing orifice in the core 8.
2
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I~igure Swivclin6 Suspended llevice VPU-1 (I) _
with Threaded String Uiseonnector (II).
On tlie core 8 and adapter 1 are cams 3 and 5 which~
aoting mutually, transmit torque to the threaded ~ t
strin~ disconnector in order to separate the drill ~
pipe from ~he casing. In the lower part of the ~
case 9 and the movable sleeve 10 there are square s
threads, along which a screwing movement and axial ~
displacement upwards oF the movable sleeve occur d -
during rotation of the drill string and the body of / - ~
the device. The gap between the core and the
- adapter is sealed by gaskets 2, and between the core 9
and the movable sleeve are packing rings il. The
inner cavity of the device, which is bounded by the
core 8, the adapter 1, the body 6 and the case 9, _
is filled with a heat-resistant lubricant that is n
injected by syringe into orifice 4. Vertical chan- ~
ncls 12 in the movable sleeve serve to equalize
~ the pressure within and without the device. The ~
drill string is attached to the adapter i,and
the threaded string disconneetor (see figure 2) with _
wliich the upper portion of the lowered section is
;ti joined to the core 8. ~
After lowering the casin~ string section to the
~lanncd depth, the well is flushed through the shoe
ol' this string, a plugging agent is pumped in, the
upper part of the two-section disconnector plug is -
forced through in order to cut off the suspended -
lower part of the two-section disconnector plug, and
the pressurizing liquid is injected. In so doing,
the drill string remains motionless when it is placed in a part of the
wcll bore that is not dangerous with regard to sticking (the intervals of
deposition of the impsrmeable rocks or of a cased well bore), or they are
, rcciprocated when they are situated in a portion of an uncased well bore =
that is hazardous from the standpoint of sticking and the weight of the
section or casing string and the state of the well permit them to be
reciprocated.
Aftcr receivin~ the stop signal, the cementing head is dismanLled and the
movable sleeve of the device is shifted upwards by rotating the drill
string to the right by 8-10 turns, and the flushing orifices are opened.
Then direct circulation through the device's flushing orifices is reestab-
lished and all the plugging agent that was raised above the disconnectors
is rinsed off, rctating the drill pipe in so doing.
During the OZTs period the drill string is flushed and periodically rotat-
ed. At the conclusion of the OZTs period the drill string is lowered with
cranking until the cams of the swiveling device are joined. With later
3
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rotration the drill string is disconnecl;ed from ~he s~etion of thc casxng ~
strin6 ~zt thc threaded diaconnector. Tho drill string~ the swivcling sus-
pension device and ~he nipple oF the ~hreaded string diaconneetior are
lii'ted to th~ surface.
Using the VPU-1~ a well bore was cased for the first time in accordance
with the described technology on 14 ~15 December 1974 at Gudermes well No
'L00 with a 340-mm section of casing string 1,518 meters in length and 155
tons in weight. The casing string section was hung on a cement rock in t}ic
opc:n w~11 borc nt the intierval of 3,~1~6-1~928 meters. The plugging agent
lhut wus rttised above the diseonnector was rinsed off in 30 minul.es with
iiiter~s ive flushing ( through the orifices in the VPU-1) and simultanec~us
- rotnLion of the drill strir?g. Later, 8 hours after the mixing of the last
portion of the plugging agent (when setting had ended), the drill string
was disconnected From the casing string, and this operation went success-
fully thanks to the absence of a loading on the zone of the left-handed
threads of the string disconnector. It should be noted that at Gudermes
well No 200, after complete lowering of the string section and prior to
receiving the stop signal, the drill pipe was motionless~ since it was lo-
cated in a portion of the open well bore that was not hazardous from the
- standpoint of sticking. However, in many wells the drill pipe must not
remain motionless in an unca5ed well bore during the entire casing period
~ because of the danger of adhesion but the gre~t weight of the lowered
. pipe~ the small radial clearance and the condition of the well bore do not
permit it to be reciprocated. In this case, beg~nning with the moment the
section is lowered all the way and until the drill pipe is disconnected~
it must be rotated periodieally.
Hor i:he sectional casing of a well, where thcsc ~rcrequisite5 arc bcin~;
�I~~~~~v~~~t, a threadless sleeve that tightly covers the flushing orifices
is installed, instead of the movable sleeve 10, and atLached with pins on
the swiveling suspension device, and a device similar to that shown in -
figure 1 is joined to the well bore. -
This is how the well bore of Braguny well No 68 was first cased at the
'1,591-1,561 meter interval with a 324-mm section of casing string. After
lowering the section, which was 1,030 meters long and weighed 103 tons,
the well was flushed and cemented through a special cementing head that
- was installed on the swivel that was joined to the drill string, which
was rotated periodically to avoid sticking. Cutoff of the suspended dis-
connector plug and opening of the flushing orifice (see figure 1) were
accomplished by discharging balls 65 and 75 mm in diameter from the c~e- _
menting head into the drill pipes. After the flushing orifices were
opened, intensive flushi.ng was executed with continuous rotation of the
drill pipe in order to rinse off plugging agent above the upper part of
the section. Later, before setting of the plugging agent, the drill
string was rotated periodically during the flushing process. The drill
pipe was disconnected from the casing string successfully.
- At present VPU-1-355 devices are being used to lower 426-, 377-, 351-,
340- and 324-mm strings, VPU-1-238's to lower 299-, 273-, 245- and 219-mm
4
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;~tr:ings. Also, a VPU-1-176 device ha~ been developed to lower 19~1-, 1?8-
und t68-~nm str~ings.
'I'hc dcvices' specii'io~tions are shown in table 1. .
'rtiblc t
- Characteristics VPU-1-355 VPU-1-238 VPU-1-176
Standard diameters of lowered easing -
string, mm 426, 377, 299, 273, 194, 178,
351, 340, 245, 219 168
324
Maximum load-lifting capacity, tons-�force 150 100 35
Maximum operating pressure, kilograms~
force/square centimeter 200 200 250
Pressurization, kilograms-force/square
centimeter 300 300 375
Maximum environmental temperature during
operation, degrees C 150 150 150 _
Diameter of the device, mm:
Outer, maximum 355 238 176
Inner, minimum 102 60 50
Conneeting threads:
Upper Z-14? Z-14? Z-121
Lower Z-147 Z-147 Z-101
The swiveling suspension device is used repeatedly. Thus, 12 sections of
casing string have been lowered with the use ~f one VPU-1-355.
Data on ~vells in which casing s~ring sections were lowered with use of
the VPU-1 installation are sho-vm in table 2. Not once was a failure of
the VPU-1 to operate noted. _
Thus, operation of VPU-1 devices has indicated their efficiency~ high ef-
fectiveness and reliability.
BIBLIOGRAPHY
1. "Instruktsiya po krepleniyu neftyanykh i gazovykh skvazhin" [In-
structions; for Casing Oil and Gas Wells]. Minnefteprom [Ministry of -
Petroleum Industry], USSR Mingeo [Ministry of Geology], Mingazprom
[Ministr;~ of Gas Industry] and VNIIKRneft', 1975.
2. Levin, Ye. M. and Vaulin, V. P., "Spusk i podveska khvostovnikov pri -
kreplenii skvazhin" [Lowering and Suspension of Adapters During the
Casing of Wells]. Groznyy, Checheno-In~;ushskoye Khizhn. 1zd-vo, 1970.
3. Rakhimov, A. K. "Ustroystvo dlya spusk i tsementirovaniya obsadnykh
kolonn sektsiyami" [A Device for Lowering and Cementing Casing Strings
5
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6
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" in 5ections], ItIT5 [ttegional Industrial-Lngineering 5ervice] ~"13uren-
iye" [Drilling] 5eries, issue 12, Moscow, VNIIO~NG [All-Union Scien-
L-ific-ftesearch Ins~itute for the Organiza~ion, Management and Ceonom-
i cs of i:hc Petrol.eum and Gas Indusi:ry] , 1968.
- Ashraf'yun, M. 0., Dulatov, A. I. et al. "Krepleniya ~lubokikh skva- _
~ �r,hin" [Casing Deep We11s], '1'NTO, "Bureniye" series, M., VNIIOENG~ 1971.
5. "5pravochnik po krepleniyu neftyanykh i gazovykh skvazhin" [Handbook _
on Casing Oil and Gas Wells], Moscow, Nedra, 1977.
COF'YItICHT: Vsesoyuznyy nauchno-issledovatel'akiy institut organizatsii,
upravleniye i ekonomiki neftegazovoy promyshlennosti
(VNIIOENG), 1979.
11409
CSO: 1822
7
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FU[tiLS AND R~LATCD CQUIPMENT
UDC 622.244.62
METIiOD I'OR FORMATION-TESTING OF CASED WELLS DE5CRIBED
Moscow QURENIYE in Russian No 4, Apr 49 signed to press 20 Jun 77 pp 27-30
[Article by V. D. Banchenko, L. A. Kuznetsova and Yu. M. Mesnyankin (Vol-
gogradNIPIneft' [Volgograd Scientific-Research and Design Institute for
the Oil Industryl: "Experiment in Testing Reservoirs at Cased Wells at
Lower Volga Fields"] -
[Text] Testing of wells during drilling enables oil ar?d gas deposits to
be observed and reservoir characteristics of the productive beds to be _
assessed. However, by virtue of the short time in which testing is con-
ducted in an uncased well, this evaluation is not always trustworthy. The
testing of wells with cased production strings can be one of the methods
for obtaining exhaustive information about a bed. Along with fulfillment
of the main ta~k--evaluation of the productivity of the beds being
studied--it is possible, in so doing, to solve various problems that arise
frequently during testing, for example, those connected with failure of
the casing string seal, complexity of the installation of the cement plugs
and others. The solution of all these problems complicates testing and ~
requires large time expenditure. The Nizhnevolzhskneft' [All-Union Pe-
tr~leum Association of the Lower Volta] testing of exploratory wells by -
means of formation testers that are lowered on the pipe is findii~g wide
application; as a result of this, an industrial flo~�r of oil or gas has ~
been obtained from a number of explorational wells with testing by means
~ of KII.
The results of the testing of certain wells are shown in table 1.
Cased wells have been tested by means of KII in several instances. The work
done at exploratory well No 67 of the Semenov area can serve as an example
of such a test. -
This well was drilled to a depth of 4,870 meters and was cased by a 168- `
mm production string to a depth of 4,847 meters. Testing was conduGted at -
- the interval of occurrence of the Sargayev strata.
On comp~.etion the well gave 150,000 m3 per day of crude (with a225-mm flow
bean) at a well-head pressure of 60-80 kgs [kilograms-force]/cm . After a
8
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;;hc~rt l.imc interval, the we11's outpu~ was Flooded and soon it bcgun to
;~,I~~~w c~ril,y wnLr.r~. 'I'hc wcll-he~d preasure Ai; ~his i:.ime fell tn icro. 1n
Lc:~Lirib Lhu ,~,irguyc:v ~LruLa [br inflow in this region, water satur~tion
theraoF had not been noted previously~ so t}ie suggestion arose that the
flow of watcr was connected with loss of seal of the casing string. In
~rder to clarify the causes of flooding of the well's output, it was de-
c.ided to test the well with a KIT2-95 with a eupport on ~he casing-
~ stri.n~ wall, using a YaM 95/ifi8 anchor. A packer was installed at a depth -
of 4,760 meters. As a result of a test for inflow that lasted 2.5 hours,
iL wus esi;zblished that the well flow was 20 m3 per day at a differential
pressu.re o[' 152 4cgs/cm~~. The output was a mix of c;ril? ~.ng mud and oil.
_ 'fl~c E~roductivity cocfficient during the test turned ~ut to be 0.165 m~~ _
cm'~/day�lcgs, L-hc coefFicient of hydraulic eonductivity was
U� cm
~1.3'L~II , reservoir pressure was 636 1cgs/cm2, and coefficient of the
status of the bore zone--2.2, that is, the bed was somewhat polluted.
During testing, ~~ater did not appear from the well.
Table 2
Well Depth Duration Testing
No Area, horizon interval, of test, results
meters hrs-min Output F3�W'
m /da
2 Narimanovskaya, Sakmara- -
Arti 2,153-2,185 1-38 Gas 100,000 -
50 Kamyshinskaya, Sargayev... 4,731-4,827 4-00 Oil 70
7~! Yurhno-Umetovskaya,
tiargayev 4,794-4,803 0-36 Oil 372
- 236 Tingutinskaya, Jurassic 1,384-1,415 1-21 Oil 480
- 'L62 Lobodinskaya, Nizhnyy
[3ashkir 4,294-4,304 1-00 Gas 187,000
- 67 Semenov, �argayev......... 4,847-4,870 7-00 Oil 60
5 Novo-Korobkovskaya, Yevla-
novsko-Livenskiy........ 2,568-2,590 2-08 Oil 600
1 Krapovskaya, Vereyan...... 2,980-3,087 1-12 Gas 190,000
For purposes of lengthier observation over well operation, the testing
- was repeated with the use of a simplified configuration of the bottom
_ hole equipment.
The well-head connections during the test are shown in figure 1.
A filter, a YaM 95/168 anchor, a packer and a pressure equalizer, the ar-
rangement of whic}~ is shown in figure 2,were lowered into the well. The
use of the pressure equalizer in this case had a definite advantage: an
acceleration in filling the pipe during descent and replacement of the
drilling mud with water in the pipe in order to create a differential
pressure without the use of a packer, and also the possibility for killing
the well during installation of the packer.
- 9
FOR OFFiCI~1i. L'SE OtiLY
APPROVED FOR RELEASE: 2007/02/09: CIA-RDP82-00850R000100070041-8

APPROVED FOR RELEASE: 2007/02/49: CIA-RDP82-44850R000100074441-8
I~OIt O~~ICIAL US~ ONi.Y
I~ i~;urc 1. U i u~rxm ut'
Wc I I ~II~uJ Cunn~cLi.onK ~
t)uring N'ormation Test-
~ ing c~f tt Well by Means ~(B)
oC KII. ; ' t
i
1. F:lev~tor. ~ _
�
, 2. Swivel head. <
' 3. Flow-b~an set. ~ ~A~
A. Separator.
C Me~xurin~ tnnk. s ~
_ A. To thc: TsA. ~ , -
.
l;. To Lhc flarc. - '
-
_ - -
. � . , . .
, ? -
? ~igure 2. Prnssure Equalizer.
1. Upper adapter.
2. Rod.
3. Nousing. -
~ ~ 4. Orifice for flushing. -
5. Lower adapter with seals.
4 `
~ s '
- After the pipe was filled with water~ the packer was :yn- rf
' stalled and the drain line opened. The well operated with
incrcasing intensity. In 3.5 hours~ when all the water
had come out of the pipe, the well began to flow~ giving
crude with a large gas content. Tt~e well-head pressure -
~ fluctuated within the 10-30 kgs/cm range; the average
flow was 60 m3/day (according to tank measurements). The
gas, which was isolated in the separator, was discharged
in a flare. Since a 12~nm diameter flow bean was installed
at the well head, the pressure differential was greater than occasioned by
thc substa.~tial gas factor.
Figure 3 shows the change in bottom hole pressure when the well worked
with the installed packers. It is evident from Figure 3 that the maximum
differential pressure was 420 kgs/cm2, and the pressure drop at the packer
was 538 kgs/cm2. eecause of this, the packer's seal was broken after
7 hours of operation and the test was cut short.
O~eration of the well at a high pressure differential confirmed the lack
of inflow of water from the 5argayev strata and indieated a high resistance
' of the components of their rocks, which had not been destroyed and were
- not carried to the surface.
10
FOR acFICIAi. L'SE 01'LY
APPROVED FOR RELEASE: 2007/02/09: CIA-RDP82-00850R000100070041-8

APPROVED FOR RELEASE: 2007/02/49: CIA-RDP82-44850R000100074441-8
~O~t O~FICIAL U5~ ONLY
Figure Uiagr~m df Ch~n~e of Battom-Hnle
hresqure Uuring Opcratidn of 5~m~n~v Well No
- 67, with p~ckcr Installed.
~ 1 ~ Nl ~f! Ki
%nr (t)
n. Cnm 1eLion of
descent nf acker and its yre~!~i~N~ ~ r
p p l70 ~~c%H
instulluti.nn. i ~~j
- b. til.~rL ot' wcll operaL-idn. i fo6~rr/u
c. hnd of output of w~ter. e
d. Momcnt of loss of packer seal.