Transcript
Page 1: Oil&Gas Eurasia July-August 2011

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The latest cutting-edge tech solutions!"#"$%&'" #()#(*%+,- - #"."/-0 $10 %+#(21-

www.oilandgaseurasia.com

The latest cutting-edge tech solutions! *

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Gazprom and EU Still Wrangle While Gaz de France Agreed Terms Til 2030 Long Ago

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TECHNOLOGY, PROJECTS & TRENDS IN RUSSIA & CIS - UPSTREAM, DOWNSTREAM, PIPELINES, OFFSHORE

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Rosneft and BP –

Why Their Big Arctic Deal Failed

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Diamonds in the snow. Did you notice them scattered on the ice floes pictured on our cover? OGE’s Chief Designer Peter

Degtyarev crafted the image as a metaphor that speaks to the wealth that lies beneath the ice and even further beneath the sea bottom.

We are focusing our July-August issue on the offshore and the search for these hidden trea-sures. This issue of OGE will be distributed at two offshore conferences, Russian Artic Offshore CIS in St. Petersburg and Offshore Europe. Visit www.oilandgaseurasia.com and click the “Events” sec-tion for more information.

It is at conferences like these that decision makers and technical specialists exchange ideas on how best to develop these subsea riches. The environment in which they work is extreme and the technologies needed to conquer them are com-plex and expensive.

Our cover story is an inside look at what went wrong with Rosneft’s attempt to partner with BP on Russian Arctic projects. We know the deal went wrong and we know why. BP and TNK-BP are family and they quarrel among themselves a lot. Unfortunately these family quarrels happen a lot in Russian business and all too often they are interpreted outside of Russia as “anti-foreign investment.”

That’s not true. TNK-BP was sticking up for its contractual rights. And now Rosneft is looking for new partners. And top of the list are the Chinese. Rosneft is talking with CNPC, Sinopec and CNOOC, but also with Exxonmobil, Shell, and the Indian nation-

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al oil company ONGC, and Brazil’s national oil company Petrobras. As OGE quotes Rosneft president Eduard Khudainatov: “The whole world is interested in the Arctic.”

Rosneft’s immediate objective in working with a foreign partner in the Arctic is to legitimize the assets it acquired from the nationalization of YUKOS. Concluding an agreement with a “brand name” in the global oil and gas industry would require a level of due diligence that would disperse the cloud that hangs over the YUKOS deal.

But the real thing to watch, in my opinon, is the prospect of the Russian state selling off control of Rosneft sometime in the next few years. Such a development would open the door to a foreign company actually owning assets in the Russian Arctic.

Times are changingWe continue this global theme into the technology section this month with a

guest technology article from Vitaly Chernikov, an engineer with Lufkin Industries. Though Russian operators favor the ESP as an artificial lift solution far more than their colleagues outside of Russia, when it comes to heavy oil, beam pumping units are the best. There is plenty of heavy oil in Tatarstan, Krasnodar and Komi where Russian operators do use beam pumping units. In his contribution to Oil&Gas Eurasia, Chernikov gives readers a wider perspective with information on how high technology equipment, such as Lufkin’s Mark II pumping units were able to resolve artificial lift problems in Venezuela.

Finally, I’d like to put in a plug yet again for the SPE Arctic & Extreme Environments Conference & Exhibition October 18-20 in Moscow. Don’t forget that Oil&Gas Eurasia is the official publication of the event and we’ll be also producing the show daily newspaper and the official exhibition catalogue. Visit oilandgaseur-asia.com and click on the SPE banner.

Meanwhile, enjoy the rest of the summer. We look forward to meeting you on the conference trail in September and October. In addition to the offshore events men-tioned above, you’ll find Oil&Gas Eurasia at events in West Siberia in September including Tyumen and Surgut, also the EPC downstream technical conferences that occur each year in Moscow. And of course there is KIOGE in early October.

See ya’ll there.

Page 5: Oil&Gas Eurasia July-August 2011

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Page 6: Oil&Gas Eurasia July-August 2011

4 Oil&GasEURASIA

CONTENTS | !"#$%&'()$

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Äîïîëíèòåëüíàÿ èíôîðìàöèÿ ñîäåðæèòñÿ íà ñàéòàõ largeo.com è iongeo.com/Russia.

Àëüÿíñ LARGEO-ION îáúåäèíÿåò òåõíîëîãè÷åñêóþ ìîùü ãðóïïû ION GXT Imaging Solutions ñî çíàíèåì ðîññèéñêîãî ðûíêà è áîëüøèì îïûòîì îáðàáîòêè ãåîôèçè÷åñêèõ äàííûõ êîìïàíèè ËÀÐÃÅÎ è ïðåäîñòàâëÿåò íåôòåãàçîâûì êîìïàíèÿì â Ðîññèè è ÑÍà óíèêàëüíûå âîçìîæíîñòè ïåðåäîâûõ òåõíîëîãèé GXT, âêëþ÷àÿ: ðàñ÷åò ñòàòè÷åñêèõ ïîïðàâîê è îáðàáîòêó äàííûõ - äëÿ ðåãèîíîâ ñî ñëîæíûìè ïðèïîâåðõíîñòíûìè ñêîðîñòíûìè àíîìàëèÿìè îáðàáîòêó äàííûõ øèðîêîàçèìóòàëüíûõ ñúåìîê �– äëÿ ìîðñêèõ è íàçåìíûõ ñåéñìè÷åñêèõ èññëåäîâàíèé 3D ñ ïîëíûì íàáîðîì óäàëåíèé ïî êàæäîìó àçèìóòó 3D SRME �– äëÿ ýôôåêòèâíîãî ïîäàâëåíèÿ êðàòíûõ îòðàæåíèé îò ñâîáîäíîé ïîâåðõíîñòè ïîñòðîåíèå ñêîðîñòíîé ìîäåëè �– ìåòîäîì ãèáðèäíîé ñåòî÷íîé òîìîãðàôèè 3D ñ âûñîêèì ðàçðåøåíèåì ïîëíûé êîìïëåêñ àëãîðèòìîâ ãëóáèííîé ìèãðàöèè äî ñóììèðîâàíèÿ (PreSDM) �– ìåòîä Êèðõãîôà, ëó÷åâîé ìåòîä, ìèãðàöèÿ ìåòîäîì âîëíîâîãî óðàâíåíèÿ (WEM) è ìèãðàöèÿ ìåòîäîì îáðàùåííûõ âðåìåí (RTM), âêëþ÷àÿ àíèçîòðîïíóþ ìîäåëü TTI RTM �– äëÿ îòîáðàæåíèÿ âåðòèêàëüíûõ áîðòîâ ñîëÿíûõ òåë, à òàêæå ñòðóêòóð, ðàíåå ñêðûòûõ ñîëüþ îáðàáîòêà ìíîãîâîëíîâûõ äàííûõ �– îïèñàíèå ñëîæíûõ êîëëåêòîðîâ ñ ïîäàâëåíèåì ïîìåõ è èñïîëüçîâàíèåì âñåõ ïðåèìóùåñòâ ïîëíîãî âîëíîâîãî ïîëÿ, ðåãèñòðèðóåìîãî îäíîòî÷å÷íûìè äàò÷èêàìè òèïà VectorSeis

Ïåðåäîâûå òåõíîëîãèè îáðàáîòêè ñåéñìè÷åñêèõ äàííûõ â Ðîññèè

Çíàíèå ñåéñìîãåîëîãè÷åñêèõ óñëîâèé Ìåæäóíàðîäíûé îïûòíûé îïûò Ïåðåäîâàÿ òåõíîëîãèÿ

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CONTENTS | !"#$%&'()$

Oil&GasEURASIA

www.oilandgaseurasia.com e-mail: [email protected]

MOSCOW ADDRESS 67/1 Koptevskaya Ul., Suite 111, Moscow 125009, Russia. Tel./Fax: +7 (495) 781 8837 / 781 8836. Oil & Gas Eurasia Monthly is published in Moscow by Eurasia Press, Inc. (USA) and is registered with the Ministry of Press and Mass Media of the Russian Federation; Certificate # 77-16277. OGE monthly is available by subscription and is distributed at industry events worldwide. Subscriptions available through catalogues: edition # 2 to the Rospechat catalog for newspapers and magazines (entry # 45834), Pochta Rossii (entry # 12632), Rospechat (entry # 84552), Rospechat NTI (entry # 66790).ISSN 1812-2086Press Run: 12,000 © 2011, Eurasia Press, Inc. (USA) All Rights Reserved.

!"#$"%&' ()*+,125009, !"#$%&, '(. )"*+,%#$&-, .. 67/1, "/0# 111.1,(.//&$#: +7 (495) 781-88-37, 781-88-36.2'34&( «5,/+6 0 7&8 9%3&80- !&4/(0» 08.&,+#- % !"#$%, «9%3&80- :3,##, ;4$.» (<=>) 0 8&3,70#+303"%&4 !040#+,3-#+%"? @A *" .,(&? *,B&+0, +,(,3&.0"%,C&40- 0 #3,.#+% ?&#-#"%DE $"??'40$&F0G. @,70#+3&F0"44DG 4"?,3 77-16277. 2'3-4&( 3&#*3"#+3&4-,+#- *" *".*0#$,, & +&$H, 4& $"4/,3,4F0-E 0 $3'*4,GI0E ?,H.'4&3".4DE ?,3"*30-+0-E 4,/+-4"G "+3&#(0. :".*0#$' 4& !"# ?"H4" "/"3?0+6 B,3,8 ."*"(4,40, J 2 $ $& +& (" 7' «K& 8, +D. 2'3 4& (D» «@"# *, B& +0» (J 45834), $& +& ("7 «:"B+& @"##00» (J 12632), $&+&("7 «@"#*,B&+0»(J 84552), $&+&("7 51; «@"#*,B&+0» (J 66790).10 3&H: 12 000 L$8. ISSN 1812-2086 © 2011, «9% 3& 80- :3,##, ;4$.» (<=>) M#, *3&%& 8& C0 C, 4D.

«MNO1». . . . . . . . . . . . . . . . . . . . . . . . . . . . . .Front CoverINOVA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Back CoverTMK . . . . . . . . . . . . . . . . . . . . . . . . . . Front Inside CoverOffshore Arctic . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3ION . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5Emerson . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7«N'(6F,3 P,?+,E» . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 9«A"Q"#». . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11

AUTUS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 12PDC. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13Simaco . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13Mac Gregor. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 15Lufkin . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .17, 19Hyperion . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 21Nalco. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 25SPT . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 27

Alcoa. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 31«5"%&- R3&» . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 33PGS. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 35Linde. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 43«:0+,3 K&8» . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 45«<0Q4,/+,7,"/080$&». . . . . . . . . . . . . . . . . . . . . . . . 47«O)S». . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 49«<,%,3#+&(6-?,+08» . . . . . . . . . . . . . . . . . . . . . . . . . . 67

INDEX OF ADVERTISERS | !1)!"+ %$+/':"#'*$/$6

#7-8 July–August 2011

6

EQUIPMENT | "3"%4#",'()$Cables That Perform BetterB%'%,;, "%?(,%:E.# +*DC#GYROSCOPES | 0)%"!+"1-New Heights for Downhole DrillingF(9;# 9;&(,; 0+7 '%$+(''(-'%-"%9+#''(6( ?*"#'.7INFORMATION SYSTEMS | )(9"%:'<)"((-$ !)!*$:-Advantages of LIMS Integration with Corporate Information Systems – Meet Solutions from Thermo Fisher Scientific!"#.)*E#&,9% .',#6"%3.. LIMS & $("-("%,.9';). .'2(")%3.('';). &.&,#)%). – "#C#'.7 (, Thermo Fisher Scientific

DOWNHOLE TOOLS | ,(4*%)!+,'&)((-6 )(!*%4:$(*Funing Hongda Petrochemical Machinery Co.Presents Innovative Technical Equipment for Russian Oil&Gas Sector

B()-%'.7 Funing Hongda Petrochemical Machinery Co-"#0+%6%#, .''(9%3.(''(# ,#/'(+(6.D#&$(# (?("*0(9%'.# 0+7 '#2,#6%1(9(4 (,"%&+. 5(&&..

ENGINEERING SURVEYS | )(&$($%(-$ )2-!+'()=Advanced Offshore Sakhalin Development TechnologyL(9"#)#'';# ,#/'(+(6.. (&9(#'.7 L%/%+.'&$(6( C#+J2%

PUBLISHER & EDITOR IN CHIEFPat Davis Szymczak [email protected]

CHIEF DESIGNER& PRODUCTION MANAGERPyotr Degtyarev [email protected]

MANAGING EDITORElena [email protected]

DIGITAL PRODUCTS DEVELOPMENT MANAGERDave [email protected]

SENIOR EDITOROlga Hilal

CONSULTING EDITOR Dr. Mi!o Sole!a, CEO, CMS Prodex

COVER COLLAGEPyotr Degtyarev

TRANSLATIONPredstavitel Service,Sergei Naraevsky

CIRCULATION ANDSUBSCRIPTIONSElena [email protected]

ADVERTISING SALES / RUSSIA Marina Alyoshina (Rus) Anna Bovda (Eng/Rus) [email protected]

-.)($+/0 - 1/(%2&' *+)(3$"* :L+ TL %0# =0? B&$ [email protected]

1/(%2&' )-.('2+* - 4+2+)5+* !" !*"-.%"),$%6:,+3 T,7+-3,%[email protected]

%&!6,3(78-' *+)(3$"* 9(,4& 2'[email protected]

4+2+)5+* !" *(.%-$-7 9-:*"%&; !*")63$"%TLG% )"4.30#[email protected]

,$(*<-' *+)(3$"*O(67& P0(&(

*+)(3$"*-3"2,6/0$(2$T-3 !0I" <"(,I&, CEO, CMS Prodex

:"$"3"//(5 2( "=/"53+:,+3 T,7+-3,%

!+*+%") «:3,.#+&%0+,(6 <,3%0#»,<,37,G 5&3&,%#$0G

*(,!*",$*(2+2-+ - !")!-,3(9(,4& U'4,%&[email protected]

"$)+/ *+3/(4& - !*")(5 / *",,->!&304& >(,I04& >44& O"%.&[email protected]

is a Member of:

U.S. SALES [email protected]&Gas Eurasia HoustonGalleria Tower 1, 2700 Post Oak Blvd., Suite 1400, Houston, TX 77056Tel.: +1 832 369 7516Fax: +1 281 657 3301Call Toll Free fromwithin the U.S.: +1 866 544 3640 EUROPEAN SALESAnna [email protected].: +7 (495) 781 8837Fax: +7 (495) 781 8838

ITALY SALESDario Mozzaglia [email protected].: +39 010 583 684Fax: +39 010 566 578 CASPIAN SALESMedina Pashaeva, Lala Abdullayeva [email protected].: +99 412 4933189, +99 412 4934507Fax: +99 412 4932478Mobile: +99 450 2223442

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Oil&GasEURASIAFor more Tech Trends, visit www.oilandgaseurasia.coma.ccom8

! "#$%&'()*%'*+ ,-*./-// Baker Hughes %-0 1-&2*3*4*%'56 *7#)(8/+ 7*04/-*9: 9*4)#"#''*# 9&%'*

!"#$%&'( Baker Hughes ")*(+',% " -$.-/0 -+"01" &"+02301" -.4&% Blue Tarpon™, $504&%6&%70&&"1" 4,( 89: ' '&;0&-'<'/%='' 4")>7'. ?4&" '6 /5.$&023'@ -.4"+ $" '&;0&-'<'/%='' + #'50 ' -04A#"0 -.4&" + -"-;%+0 <,";% Baker Hughes, Blue Tarpon, 4,'&"2 91 #, $504&%6&%70&" 4,( +>$",&0&'( +>-"/"'&;0&-'+&>@ #%-3;%)&>@ 5%)"; $" ")5%)";/0 $,%-;% - =0,AB +>6"+% $5';"/% $5' 50%,'6%='' -,"C&>@ #"5-/'@ $5"0/;"+. D.4&" '#00; "4&' '6 ,.73'@ @%5%/;05'-;'/ + #'50 $" +"6#"C&"-;' $050+"6/' 6&%7'-;0,A&>@ ")*0#"+ $5"$$%&;% ' C'4/"-;' ' #"C0; +>$",-&(;A -,"C&"0 #&"1"$,%-;"+"0 6%/%&7'+%&'0 )06 &0")@"4'-#"-;' +"6+5%E%;A-( + $"5; 4,( 4"6%$5%+/'. D.4&" -05;'<'-='5"+%&" F#05'/%&-/'# )B5" -.4"@"4-;+% (ABS).

G%/-'#%,A&%( #"E&"-;A &%-"-% -.4&% – 80 )%55./#'& (9 250 ,/#'&) + #'&.;., ")*0# $5"$$%&;% – 2,1 #,& <.&;"+ (952,5 ;). D.4&" 5%--7';%&" &% /"#%&4. '6 44 70,"+0/. Blue Tarpon #"C0; /5.1,"-.;"7&" +>$",&(;A 5%)";> &% 1,.)"-/"+"4&>@ #0-;"5"C40&'(@. D.4&" "-&%E0&" 10 &%-"-%#' +>-"/"1" 4%+,0&'(, /";"5>0 5%6#0E%B;-( + $",&"-;AB ";1"5"C0&&"# ";-0/0 4,( 6%E';> ")"5.4"+%&'( "; +&03-&'@ +"6402-;+'2. H%-"-> ")0-$07'+%B; 1'45%+,'70-/.B #"E&"-;A 24 ;>-. ,.-. ' -/"5"-;A 6%/%7/' 4" 32 ;>-. <.&;"+ (14,5 ;) $5"$$%&;% + #'&.;.. Blue Tarpon ;%/C0 "-&%E0&" -'-;0#"2 4'&%#'70-/"2 -;%)','6%='' DP-2 - 4+"2&># H:I ' "4&'# /"5#"+># :I. D'-;0#% -$5"0/;'5"+%&% -$0-='%,A&" 4,( ")0-$070&'( )06"$%-&"2 5%)";> + ,B)>@ #0;0"5","1'70-/'@ ' #"5-/'@ .-,"+'(@.

Linde 457&9./-( 9#)/; 7*).(./4'56 1(<*('(-/<(.*)*4 G-TECTA™

!"#$%&'( Linde Gases, $"45%640,0&'0 Linde Group, ")*(+',% " &%7%,0 +>$.-/% &"+"2 -05'' $"5;%;'+&>@ $5'-)"5"+ ")&%5.C0&'( 1%6% G-TECTA™. 9%65%)";%&&>0 4,( $5"--;";> '-$",A6"+%&'( ' #%/-'#%,A&"2 6%E';> "; "$%-&>@ .-,"+'2 ;5.4%, 1%6"%&%,'6%;"5> G-TECTA ™ $"4@"4(; 4,( ,B402, 5%)";%BE'@ + $";0&='%,A&" "$%-&>@ .-,"+'(@, +

Baker Hughes Introduces State-of-the-Art Vessel to Its Global Deepwater Fleet

Baker Hughes announced the launch of its state-of-the-art fracturing and stimulation vessel, the Blue Tarpon™. The 300-foot ship, one of the world’s largest stimulation vessels and the seventh vessel in the Baker Hughes fleet, is designed to provide high-rate and high-volume stimulation treatments for demanding offshore operations. With one of the largest proppant and fluid-carrying capacities in the world, the ABS† class-certified ship can perform complex, multiple-zone completions without traveling back to port for resupply.

With a maximum pump rate of 80 barrels per minute, proppant capacity of 2.1 million pounds, and accommoda-tions for up to 44 people, the Blue Tarpon is designed to perform round-the-clock operations in deepwater plays. The vessel’s 10 separate high-pressure pump units – housed in a fully enclosed structure to protect the equipment from the environment – can deliver up to 24,000 hydraulic horsepower and pump up to 32,000 pounds of proppant per minute. The Blue Tarpon also features a DP-2 dynamic positioning system with twin bow thrusters and a stern thruster specifically designed to operate safely in the widest possible weather and sea conditions.

Linde Launches G-TECTA™ Portable Gas Detection Range

Linde Gases, a division of The Linde Group, announced the launch of its new range of G-TECTA™ portable gas detec-tion instruments. Designed for ease of use and maximum

TECH TRENDS | !"#$% &%'!"(")**

The Blue Tarpon vessel is designed for high-rate, high-volume !stimulation treatments in demanding offshore operations.

!"#$% Blue Tarpon™ &'(#$)*$)+($% !#,- ./&%,$($0- ./1%2%0$3($10.$/4 5)163)7$/4 ')7%3 &% %7')7%32( &,)13) 1 8(,9: ./*%.) &'03%2) &'0 '(),0*)800 1,%;$/4 5%'1204 &'%(23%..

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Page 11: Oil&Gas Eurasia July-August 2011

9

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!"#$% & '()%#,-.*/ !0123452 6278090:55 8; <;362 www.oilandgaseurasia.rueurasia.ru

protection against hazardous working con-ditions, the G-TECTA™ range is suited to people working in potentially dangerous environments, including confined spaces, in industries such as petrochemicals and refining, welding, manufacturing and con-struction.

G-TECTA™ portable gas detectors are available in single and multi-gas versions and all are manufactured in bright red with a reflective label design to deliver high visibility when worn, ensuring com-pliance and safety. The multi-gas detec-tors, which can be configured to detect up to 26 different gases, also have upward facing visual displays, providing the user with enhanced “at-a-glance” awareness of gas levels. Additionally, all detectors are equipped with alarm systems and a vibra-tion action so the user is also given audible and physical warnings of potentially noxious gases or oxy-gen displacement. G-TECTA™ sensor technology further ensures reliability and high quality gas readings by provid-ing immediate warning indications in the case of a sensor functionality issue.

The G-TECTA range is certified to meet all global safety standards including IECEx, ATEX, UL and CSA intrinsically safe approvals and international performance safety stan-dards.

PGS Announces GeoStreamer GS (TM) – Ghost-Free Seismic Technology

Seismic data without the source- and receiver sea surface reflections (ghosts) produce subsurface seismic images of unprecedented quality and represent removal of some of the most significant noise components that the marine seismic industry have struggled with since its begin-ning in the 1960s.

Four years ago PGS solved a 40-year old industry problem by eliminating the receiver ghost with dual sensor

;"# 7'-,0 6%/5>;>@ $"#0E0&'(@, + ;%/'@ ";5%-,(@, /%/ &0<;0@'#'( ' &0<;0$0505%)";/%, -+%5/%, $5"-'6+"4-;+" ' -;5"';0,A-;+".

:" /",'70-;+. /"&;5",'5.0-#>@ 1%6"+ %&%,'6%;"5> G-TECTA™ #"1.; )>;A /%/ "4'&%5&"1", ;%/ ' #.,A;'1%6"+"1" '-$",&0&'(. J#0B; (5/"-/5%-&.B "/5%-/. -" -+0;"";5%C%BE02 K;'/0;-/"2, 7;" ")0-$07'+%0; @"5"3.B +'4'#"-;A 4%C0 $"-,0 4,';0,A-&"2 K/-$,.%;%='' ' 1%5%&;'5.0; -"),B40&'0 ;50)"+%&'2 )06"$%--&"-;'. G.,A;'1%6"%&%,'6%;"5> #"1.; ")&%5.C'+%;A 4" 26 5%6-,'7&>@ 1%6"+, % 4'-$,02 &% +05@-&02 ,'=0+"2 -;"5"&0 $"6+",(-0; - "4&"1" +61,(4% "$5040,';A .5"+&' 1%6%. !5"#0 ;"1", +-0

40;0/;"5> "-&%E0&> 6+./"+"2 ' +')5%='"&&"2 -'-;0-#%#' -'1&%,'6%='', ;%/ 7;" $",A6"+%;0,A $",.7%0; 6+.-/"+>0 ' <'6'70-/'0 $504.$50C40&'( " $";0&='%,A&" +504&>@ 1%6%@ ',' +>;0-&0&'' /'-,"5"4%. L0@&","1'( G-TECTA™ ")0-$07'+%0; &%40C&"-;A ' +>-"/"0 /%70--;+" "$5040,0&'( 1%6%, +>4%+%( #"#0&;%,A&>0 $504.-$50C40&'( + -,.7%0 -)"( <.&/='"&%,A&"-;' 4%;7'/%.D05'( G-TECTA -05;'<'='5"+%&% &% -"";+0;-;+'0 +-0# #0C4.&%5"4&># -;%&4%5;%# )06"$%-&"-;', +/,B7%( IECEx, ATEX, %;;0-;%='B '-/5")06"$%-&"-;' UL ' CSA, % ;%/C0 -"";+0;-;+.0; #0C4.&%5"4&># -;%&4%5;%# )06"$%-&"-;' $5' K/-$,.%;%=''.

GeoStreamer GS (TM) – .#6'*-*1/0 9#+9"*)(<4#%3/ 2#< *.)($#'/+ *. 3*"7('// PGS

D02-#'70-/'0 4%&&>0, + /";"5>@ &0; ";5%C0&&"1" "; $"+05@&"-;' #"5( -'1&%,% (K@%), +"6402-;+.BE01" &% '-;"7&'/ ' $5'0#&'/, ")0-$07'+%B; '6")5%C0&'( 10","-1'' )0-$50=040&;&"1" /%70-;+%: + &'@ .4%,0&> "-&"+&>0 -"-;%+,(BE'0 3.#%, - /";"5>#' #"5-/%( -02-#"5%6+04/% )"50;-( - #"#0&;% -+"01" $"(+,0&'( + 1960-@ 1"4%@.

M0;>50 1"4% &%6%4 PGS 503',' 40-,0;&BB $5"),0#. ";5%-,', .-;5%&'+ ";5%C0&&>2 -'1&%, -02-#"$5'0#&'/% - $"#"EAB 501'-;5%='' 4+"2&># 4%;7'/"# $" .&'/%,A&"2 ;0@&","1'' GeoStreamer. N 506.,A;%;0 .4%,"-A 6&%7';0,A&" 5%-3'5';A 4'%$%6"& 7%-;"; -02-#'70-/'@ 4%&&>@ 6% -70; .4%,0&'( ";5%C0&&"1" -'1&%,% 4,( $5'0#&'/%.

!5"#0 ;"1", 4+"2&"2 4%;7'/ GeoStreamer $"6+",(0; "-.-E0-;+,(;A )./-'5"+/. &% ,B)"2 1,.)'&0 )06 $";05A 4,( &'6-/'@ ',' +>-"/'@ 7%-;";, /";"5>0 -,.7%B;-( $5' ;5%4'='"&-&"2 ;0@&","1'' #"5-/"2 -02-#"5%6+04/'. N" +50#( 3;%;&"2 )./-'5"+/' GeoStreamer &% 1,.)'&0 "; 15 4" 25 # 01" .&'/%,A-

The PGS GeoStreamer GS (TM) introduces a new era of ghost-free, !broadband seismic data.

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#7-8 July–August 2011TECH TRENDS | !"#$% &%'!"(")**

Oil&GasEURASIAFor more Tech Trends, visit www.oilandgaseurasia.coma.ccom10

recording through its unique GeoStreamer. This results in seismic data with considerably broader bandwidth due to the removal of the receiver ghost.

Furthermore, the dual sensor GeoStreamer enables towing at any depth without compromising low- or high frequencies, as experienced by conventional streamer tech-nology. As the GeoStreamer is routinely towed between 15 and 25 meters depth, a significant increase in opera-tional efficiency together with a strong reduction in surface induced noise, further adds to its unique advantages.

However, the sea surface reflection on the source side still remains and represents a limiting factor in revealing the true earth response.

&>0 $50'#.E0-;+% -;%&"+(;-( "70+'4&>: 6&%7';0,A&" +>5%--;%0; K<<0/;'+&"-;A 5%)";> &%5(4. - -',A&># -"/5%E0&'0# 3.#"+, '&4.='5"+%&&>@ +"4&"2 $"+05@&"-;AB.

L0# &0 #0&00, ";5%C0&'0 $"+05@&"-;' #"5( &% '-;"7-&'/ $"-$50C&0#. "-;%0;-( -405C'+%BE'# <%/;"5"# + +>(+,0&'' ;"7&"2 /%5;'&> 60#&>@ $"5"4.

H% +0-0&&02 /"&<050&='' EAGE + N0&0 PGS ")*(+'-,' " -"64%&'' -+"02 $"-,04&02 5%65%)";/', GeoSteamer GS. O%&&%( ;0@&","1'( "-&"+%&% &% 501'-;5%='' 4%&&>@, $"6+",(BE02 .-;5%&';A K/" /%/ 4,( '-;"7&'/%, ;%/ ' 4,( $5'0#&'/%, ' $",.7';A 7'-;>2 -'1&%, 50,A0<% ' 10","1'' 60#&>@ $"5"4 – '6+07&.B =0,A ,B)"2 -02-#"5%6+04/'.

Weatherford Reservoir Monitoring Technology Optimizes Well and Formation Performance Weatherford reservoir monitoring systems include both electronic and fiber optical pressure and temperature (PT) gauges and optical

hydroacoustic flowmeters. The main advantage of fiber-optic systems is that they do not contain downhole electronics, whereas optical sensors – which operate based on the Bragg grating optical technology – are non-ageing, exclusively tolerant to vibration action, excessive temperature and pressure with very good metrological characteristics.

Optical hydroacoustic flowmeters of Weatherford represents a new class of flow measurement technology, which utilizes the principles of hydroacoustic velocity measuring vortex flow of mixture – the SONAR technology, as well as measuring sound velocity, pressure and tem-perature. This technology allows to significantly improving performance and data reliability compared to the existing systems.

Such flowmeter is installed in a tubing string, has full bore section, and has neither exposed sensors nor optical windows, which ensures full access of the running tool to bottom-hole. However, there are various configurations: single-phase flowmeter is designed for multi-zone pumping of fluid or gas, multi-phase – is used for intellectual completion of high-yield producing – as a rule, multilateral – wells. One triple-cored fiber-optic cable can simultaneously have, for instance, four PT gauges, two flow meters and suballocated tempera-ture profile sensor in the wellbore. The cable is fixed by protectors to the outer tubing wall and goes up through the pipe hanger and well head to the surface system of signal receive-transmit and process-ing. Surface system transmits real-time well data to the customer’s automated process control system.

Continuous monitoring of pressure, temperature and well flow rate data is necessary to optimize well and formation performance. Weatherford technology allows in full measure to take great chal-lenges of production and optimization.

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L0@&","1'( GeoStreamer GS ).40; $504-;%+,0&% + K;"# 1"4., ', $504$"-,"C';0,A&", ).40; 4"-;.$&% + <"5#%;0 3D + )",A3'&-;+0 501'"&"+ #'5% / 2012 1"4.. GeoStreamer GS $"6+",(0; .,.73';A 4%&&>0 -02-#"5%6+04/' ' $"+>-';A K<<0/;'+&"-;A -*0#/' 6% -70; .4%,0&'( ";5%C0&'2 "; #"5-/"2 $"+05@&"-;' /%/ 4,( '-;"7&'/%, ;%/ ' 4,( $5'0#&'/%.

Schlumberger 457&93(#. '*4&; 4#)9/; 94*#+ 7)*1)(""'*+ 7-(.,*)"5 Wellbore

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PGS announces its latest develop-ment, the GeoSteamer GS at the EAGE conference in Vienna in spring. This is an acquisition based solution that enables the removal of both the source and receiver ghosts thus revealing the true earth response, which for long has been the ultimate goal of any seismic experiment.

The GeoStreamer GS technol-ogy will be introduced this year, and is expected to be available in 3D in most regions of the world by 2012. GeoStreamer GS delivers better seis-mic data and more efficient operations through removal of the sea-surface reflections on both the source and receiver side.

Schlumberger Releases Latest Version of its Wellbore Software Platform

Schlumberger announced the release of Techlog* 2011 software, which delivers a next generation application interface and expansion of customization capabilities.

The new Pore Pressure Prediction module incorpo-rates industry standard methods to compute the pore pressure and fracture gradients and establish the safe mud weight window to ensure safe drilling operations. The 2011 release also sees the full implementation of GeoFrame* ELAN functionality in Techlog, augmenting the existing mineral solver capabilities with the proven algorithms

FOBOS JSC (town of Rybinsk) wins «Best Small Enterprise in Industrial Production” award

The National Gold Mercury Business Award ceremony was held at the World Trade Center in Moscow on June 9, 2011.

Valve manufacturer Fobos (Rybinsk) won “The Best Small Enterprise in Industrial Production” category. This award is the most prestigious in Russia in the field of business and is pro bono. It was established by the Russian Chamber of Commerce in 2002. Among the contestants – small Russian enterprises.

The award’s main goals are to promote entrepreneurship in Russia, give entrepreneurs the opportunity to provide the best products and services, advance domestic business models as well as to promote the ideas of social responsibility in business, strengthen the traditions of Russian entrepre-neurship, and build a respectful social attitude towards business.

Fobos JSC produces ball valves with DN 6-300 nominal size for up to 16 MPa working pressure.

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#7-8 July–August 2011TECH TRENDS | !"#$% &%'!"(")**

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from this industry recognized application. Other advanced applications such as NMR and Wellbore Imaging received significant upgrades in this release.

The 2011 release delivers a complete modernization of the application interface. The new ribbon interface com-bines highly intuitive icons with complete customization capability – to bring clarity and knowledge sharing directly into the application. A key innovation in usability, the convenient dashboard mode supports automatic window tiling to maximize the workspace and reduce mouse move-ments. Furthermore, an intelligent right-mouse-click in context brings frequently used tools and actions directly to the users’ fingertips. All of these new developments ensure a significant increase in productivity.

The powerful workflow interface enables users to cre-ate comprehensive cross-domain analysis workflows that are applicable across single or multiple wells with equal ease. Workflows can be saved and shared as templates, edit-ed and re-applied to new data facilitating consistency, ease of use and efficient sharing of expertise across asset teams.

Transkor-K Technology Makes It Possible to Assess the Efficiency of Pipeline Inspection Methods Used

The planning of pipeline overhaul and repair activi-ties, on the basis of pig-assisted inspection, has, in general, a fairly objective nature, given that the inspection quality is stated and compared in accordance with the uniform International Standard “Specification and Requirements

PG9 (NMR) ' '6")5%C0&'0 -/+%C'&> (Wellbore Imaging), $",.7',' 6&%7';0,A&"0 ")&"+,0&'0 + K;"# +>$.-/0.

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for Intelligent Pig Inspection of Pipelines”. However, such an assessment and comparison of NDT inspection methods is not applicable to facilities that cannot be subjected to intelligent pigging. As a result, in the bidding process, the selection of contractor to perform pipeline inspection is normally made based mostly on the economics of a propo-sition. At the same time, the NDT inspection branch, as a whole, needs a quantitative evaluation of qualitative indi-cators, as a tool for an entire range of innovation policies.

Based on its 10 years of inspection experience using the Magnetic Tomography Method (MTM), Transkor-K Research and Development Center is offering, for the experts’ attention, its methodology for assessing the com-parative efficiency of different methods used in pipeline inspections, to allow the making of comparison and intel-ligent choice of contractors, based on the objective results of verification.

The method’s essentials are as follows: Contractor sets feasibility of anomalies revelation and

indeficication. After that verification is performed mean-ing the establishment of correspondence between the data regarding the exact location, and the hazard level, of defective portions of a pipeline, as stated in a report, to the real parameters of the pipeline’s technical condition in the portions examined;

Verification object should meet the following require-ments: sufficient length; a large number of areas with metal faults; preparation of the surface for NDT inspec-tion throughout the entire length, without having to go through protracted approval procedures regarding exca-vation work.

Realistic parameters of the pipeline’s technical con-dition are assessed either in the check pit-holes whereby, according to the GOST R 50779.30-95 requirements, the number of inspection points shall be thirty, at least.

To assess the efficiency of inspection shall be per-formed of the points awarded every time the inspection data concur, partially or fully, with the real parameters, using special weighting factors for such an assessment.

The method’s results are considered reliable and the stated accuracy consistent when the total points awarded, following the verification, are equal to at least 70 percent of the maximum value of the fully matching results. For example this factor for MTM for Chevron oilfield objects in Indonesia - see photo - was more than 90 percent.

Based on the findings results, a Protocol (Report) is prepared, which, in accordance with the Quality Management ISO 9001:2008 requirements, gives a merit rating to the quality of the inspection performed (assessment of the contractor’s performance efficiency). Document can then be used as a basis for contractor selec-tion or for acceptance of inspection data. This approach

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Oil&GasEURASIAFor more Tech Trends, visit www.oilandgaseurasia.coma.ccom14

makes it possible to assess and improve the quality of NDT inspection work in all stages of the pipeline transport facilities’ entire life-span.

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Successful Solution of Multi-Level Problems in Crude Oil Production

http://www.oilandgaseurasia.com/news/p/2/news/11608

Schlumberger Releases Latest Version of its Wellbore Software

Platform

http://www.oilandgaseurasia.com/news/p/2/news/11606

Linde Launches G-Tecta™ Portable Gas Detection Range

http://www.oilandgaseurasia.com/news/p/2/news/11528

Eni Refining & Marketing Division Selected AspenTech’s Solution

http://www.oilandgaseurasia.com/news/p/2/news/11301

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Page 17: Oil&Gas Eurasia July-August 2011
Page 18: Oil&Gas Eurasia July-August 2011

16 Oil&GasEURASIA

Early this year, Rosneft and !" announced the estab-lishment of a strategic alliance that offered the British company the prospect access to some of the

largest hydrocarbon reserves in the Arctic, while giving the Russian company the right to be called an international company. In the end, however, the deal of the century failed to materialize.

A Sole AllianceRosneft and !" have enjoyed partnership relations for

a long time. For a number of years, both have engaged in joint geological exploration work on the Kaigan-Vasyukan license block located on the Sakhalin shelf in Russia’s Far East. Last October, the Russian state-owned company became !"’s partner in Ruhr Oel GmbH which owns inter-est in four different refineries in Germany. In addition, the British company owns a small interest (1.25 percent) in Rosneft which it received in 2006 during the conduct of the so-called “people’s” IPO.

Some newer forms of cooperation on a global scale have been agreed upon by Rosneft’s and !"’s respective new CEO’s. Last September, Eduard Khudainatov became the Russian state-owned company’s new president, while Robert Dudley replaced Tony Hayward as BP’s new General Director a mere month later. In January 2011, supported by the Russian government, the two companies signed an agreement on the establishment of a strategic alliance.

Under the agreement, the Russian state-owned com-pany was to receive 5 percent of !"’s ordinary voting shares in exchange for 9.5 percent of its own stock (with each respective share bundle being valued at about $7.8 billion). The companies would not be allowed to sell their respective newly-acquired stock for two years from the date of execu-tion of the deal. Ultimately, !" was to become the owner of 10.8 percent of Rosneft’s stock, while the Russian company was to become the second biggest owner of !"’s stock fol-lowing the BlackRock investment fund (5.9 percent).

Furthermore, the two companies had agreed on the establishment of a joint venture (67 percent interest owned by Rosneft and 33 percent by !") to engage in geologi-cal exploration and development of three license blocks known as East Prinovozemelsky-1, 2 and 3 (with the com-bined estimated reserves of 49.7 million tons of crude, 1.8 trillion cubic meters of gas and 49 million tons of conden-sate) and to conduct joint operations “within the frame-work of offshore projects in Russia and third countries”.

Oil experts christened the Rosneft-!" agreement the deal of the century and a mega-alliance. On the one hand, through an equity swap, the Russian company was to

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A Difficult Road to the Arctic!"#$%&' (#)* + ,"-).-#

Galina Starinskaya !"#$%" &'"($%)*"+

OFFSHORE ARCTIC

Page 19: Oil&Gas Eurasia July-August 2011

!7-8 !"#$–%&'()* 2011

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receive access to various international projects. That was the main emphasis of the deal to be arranged. Furthermore, in the run-up to the expected sale by the government of part of its stock, the Rosneft management was given the task of raising the company’s capitalization. Agreements with !", in the best possible way, could have enhanced the state-owned company’s stock value. On the other hand, neither Rosneft nor any other Russian company have had any previous experience of working in northern latitudes, something that is essential for running processes and operating equipment. !" was ready to offer all of that and to cover expenses for exploration work to the tune of $1 billion.

The British company’s generosity was easy to explain – first in terms of the tremendous interest in the oil and gas fields in the Russian section of the Arctic and, second in terms of !"’s need to save its reputation and seek a new region for its operations following the disastrous Gulf of Mexico spill in April last year.

Why Has the Deal Gone Wrong?The Russian oil and gas market is something that !"

has been familiar with for a fairly long time. In 2003, BP and Alfa Access Renova (AAR), a consortium owned by the Russian oligarchs Viktor Vekselberg, Mikhail Fridman and Leonard Blavatnik, established, on a parity basis, TNK-!", with a mission to operate in the territory of Russia and Ukraine. It is now Russia’s third biggest company in terms of oil reserves and crude oil production volumes. TNK-!" yields high dividends for the British company and gives it nearly a quarter of its crude oil production, while also giving it a lot of headaches. In 2008, an acrimonious row flared up between the various TNK-!" shareholders, with !" and AAR failing to agree on the joint venture’s corpo-rate strategy. The British shareholders felt that TNK-!" was expected only to operate in Russia alone, while their partners saw great prospects for operating overseas. The consortium came out the winner, and Robert Dudley, who was then head of TNK-!", had to abandon his position and was forced to leave Russia.

The Russian AAR consortium was all up in arms against the alliance between Rosneft and !", arguing that the agreement contravened the shareholder agreement within the TNK-!" framework.

It was argued that, under the agreement, !" had the right to operate in Russia exclusively through the Russian-British company, TNK-BP. Whereas the British had single-handedly negotiated a deal with Rosneft, with the joint venture’s board of directors not even meeting to discuss the arrangement. The consortium felt that it was necessary to replace the British company with TNK-!". Rosneft, how-ever, was against such a replacement, given that, in its own opinion, TNK-!" failed to meet several conditions as it was seen as not having the experience, know-how or technology necessary for the job and its capitalization being less than $100 billion.

In practice, without calculating all possible legal risks, !" had placed the deal under a threat of being frustrat-ed. Moreover, the company’s management had clearly hoped that Vice Premier Igor Sechin’s patronage and Prime Minister Vladimir Putin’s support would help bring the deal to a successful end. The government, however, decided not to intervene in the conflict. In the end, AAR was awarded a winning decision by the Stockholm Arbitration Institute WWW.LUFKIN.RU

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to which the consortium had resorted for defense of its rights. The arbitration tribunal did not rule out an ultimate possibility of alliance, but it put forward a number of conditions to be met. More specifically, it allowed it to proceed with an equity swap between !" and Rosneft, on condition that the Russian state-owned company would agree to transfer the Arctic project to TNK-!". The equity swap itself was made subject to a number of restrictions. As it was, the com-panies’ respective stocks were to be placed in a special trust fund, with stocks being only allowed to be used for investment purposes exclusively. The trust fund itself was to be managed by independent directors, with the companies not allowed to have their rep-resentatives sit on each other’s respective boards of directors. Those were, however, the sort of conditions that Rosneft was not prepared to accept.

!" sought to resolve the deadlock one way or another. It was even prepared to buy out from AAR the consortium’s own share in TNK-!" for the sum of $30 billion, including, as an option, jointly with Rosneft. According to some unofficial reports, a reverse option was considered, too, with !" opting out of the joint venture or paying smart money to AAR in the amount of $2 billion. The likelihood, however, of any of the TNK-!" shareholders making a concession and selling their share of the stock was very low indeed. Neither party was interested in doing that, given that the oil company had been a major revenue producer. Moreover, in the event of the AAR’s shares buy-out, the British company would be hard pressed to find the means necessary, given that the company was still covering the losses caused by the oil-spill accident off the coast of the US, while Rosneft was still repaying its debts in the wake of its 2004 purchase of the YUKOS stock.

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Page 22: Oil&Gas Eurasia July-August 2011

20

#7-8 July–August 2011OFFSHORE ARCTIC

Oil&GasEURASIA

#',-2#$2 6):;$#/2 ;5/#)+/- #':$&78 *)@)*. A -):9 >', 3 +&9%$' 3769;$ $6C/8 AAR, 05/-$#+6)8 6):;$#// +&)>#) 07&) 07 #$8-/ +5'*+-3$ – 6):;$#/2 'D' #' ;)657&$ 9D'50 )- $3$5// / 5$4&/3$ #',-/ 9 0'5'()3 OV=, «")+#',-.» >' *) +/@ ;)5 #' 5$+;&$-/&$+. + *)&($:/ ;)+&' ;)69;6/ 3 2004 ()*9 $6-/3)3 «WAIO$».

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firmed that officially, while not rejecting its plans for cooperation with !" and, apparently, bearing no grudge against it for the deal’s failure, even though it had previ-ously threatened lawsuits. The British company, however, found itself in a more complicated situation, given that its shareholders were very unhappy with Robert Dudley’s actions and, on top of that, its relations with the AAR con-sortium were ruined, even though they had never been perfect before. “We’ll just go on living together like a couple of quarrelsome spouses,” one TNK-!" top manager told Oil&Gas Eurasia.

Rosneft’s Looking for New PartnersWhile !" was trying to make good with AAR, Rosneft

was not wasting time either. The company had started negotiations with other foreign oil and gas corporations. Some of those on its negotiating list included the Chinese CNPC, CNOOC and Sinopec, the American ExxonMobil, the Indian ONGC, the British Shell and the Brazilian Petrobras. “We are looking into possibilities of partnership with Chinese, Indian and other companies. I mean to say the whole world is interested in the Arctic,” in the words of Rosneft President Eduard Khudainatov spoken last March.

The foreign companies’ interest in Russian offshore areas is truly colossal. Rosneft, too, needs partners to pur-sue its projects. Last year, without holding tenders, the Russian government granted Rosneft three new fields in the Kara Sea (under earlier plans they were to be developed jointly with !") and the Southern Russian block on the Barents Sea shelf. This year, the company may get a further 18 blocks, with five of them in the Barents Sea: Pomorsky, Northern Pomorsky-1 and 2, Western Matveyevsky and Southern Prinovozemelsky blocks. Rosneft has already submitted to the RF Ministry of Natural Resources a total of 28 applications for offshore blocks that it hopes to be granted before 2020, this against ten applications only from Gazprom.

The Russian company already has two American part-ners to work with on its offshore projects. One of them is Chevron with which the Russian state-owned company has agreed to develop the Western-Black Sea license block that includes Shatsky Ridge Field, while the other is ExxonMobil with which it plans to develop the Tuapse Trough. Its col-laboration with Chevron, however, is not at all a done deal yet, given that company’s certain doubts about the data concerning the in-place hydrocarbon reserves. A top man-ager with Rosneft has told Oil&Gas Eurasia that, given the US company’s earlier unsuccessful experience of drilling in the Black Sea off the Turkish coast, it was afraid that such a situation might be repeated again.

Alexei Mukhin, general director of the Center for Political Information, believes that ExxonMobil alone has a good chance of replacing !", given its vast experience and technological know-how of working on the Arctic shelf. Nevertheless, Rosneft has so far refrained from announcing any new alliances.

Rosneft’s top manager says negotiations are under way with numerous companies, with no equity swap planned with any of them. Troika Dialog analyst Valery Nesterov said that is exactly the clause in the agreement that was of greatest importance to Rosneft. He added, “Since there is no foreign company at the moment with which Rosneft could exchange shares, it is in no great hurry to make any new deals.”

Page 23: Oil&Gas Eurasia July-August 2011

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Page 24: Oil&Gas Eurasia July-August 2011

22 Oil&GasEURASIA

As soon as the Third Energy Package gained force, European energy companies spoke out sharply against the document, which Russia, for one, had

all along openly described as an anti-Gazprom docu-ment. Whether it was changes in the gas market that had made the Europeans more pliant or it was a double game they had played all along, the package has been adopted finally and time has come to make a deal with Gazprom – one way or the other – on natural gas deliv-eries. Furthermore, the EU has even voiced its readiness to support the Russian-backed South Stream gas pipe-line project. Yet to this day, it is not at all 100 percent certain that the project will be free of EU regulation.

The 6th International Conference “Energy Dialogue: Russia – European Union. Gas Aspect” held in Berlin created a certain feeling of enthusiasm in Gazprom. After all, for many years of Europe discussing and delib-erating the Third Energy Package (TEP), Gazprom, with support from the Russian government, had strongly opposed the document. Adopted in July 2009, TEP only came into effect last March.

TEP’s key provisions include the separation of the competitive and the natural-monopoly types of activi-ties and the establishment of a special certification procedure for energy transportation operators that are controlled by foreign interests. The TEP’s structuring provisions differ for the existing and for the new gas transportation systems.

Concerning the existing gas transportation sys-tems, the EU member states are free, at their discretion, to apply any one of the established three separation models.

The first, and also the strictest, separation model provides for complete separation based on ownership, meaning that a vertically integrated company will lose its rights of ownership and control of a gas transporta-tion system in question.

The second model provides that a vertically inte-grated company will transfer its functions of a gas transportation system control to an independent sys-

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tem operator while, at the same time, remaining the pipeline owner (medium level of strictness).

The third, and the softest and most popular, option means that a vertically integrated company will trans-fer its right of ownership of a gas transportation sys-tem in question, together with all its control functions, to one of its affiliated companies, which has to be “reli-ably insulated” from other corporate segments.

Each of the EU member states is entitled to choose between the three existing options for incorporating the TEP’s provisions into the body of its national laws.

In respect of the new systems, only the third, and the strictest, option applies, with complete separation, in terms of ownership. The only possibility to avoid doing that is to achieve a waiver of regulation through a two-tier process: from an EU member state that allows the system to pass through its territory, and at the European Commission level.

Gazprom has issued a statement saying that apply-ing TEP principles may have negative consequences for the company’s execution of its long-term gas-supply contracts and for the prospects of attracting invest-ments into construction projects for new gas pipelines in Europe.

The European Commission replied saying that TEP regulations apply to all gas suppliers to Europe. It

Alexei Miller, Gazprom Management Committee Chairman, and !

Jean-Francois Cirelli, President of Gaz de France (left to right), have signed an agreement in 2006 to prolong the existing contracts on Russian gas delivery to France until 2030.

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#7-8 July–August 2011GAS SUPPLY

Oil&GasEURASIA

'('<*--' -# E'-* "*$4.@ .$7*-*-.5 -# 2#$'+'7 "8-4*, +8$+#--8@ ,"#2*9.*5 + R&'-.., # ,#4>* &').,.6*(4.7. ('<8,./7. + QE".4*.

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should be noted, however, that Norway soon is likely to lose its status as a major gas supplier due to its slump-ing gas reserves, while Algeria and Qatar are mostly in the business of supplying liquefied natural gas rather than pipeline gas and, as a result, they are not so closely tied to the pipeline infrastructures.

On the whole, Europe has been urging Russia to allow foreigners much freer access to its gas produc-tion operations, based on their openly articulated concerns about Gazprom’s ability, on its own, to secure the massive investments into ensuring gas production capacity volumes necessary to satisfy the international market demands.

Furthermore, some of Gazprom’s major custom-ers have all along complained of what they perceive to be the Russian company’s overly high prices set in its long-term gas supply contracts tied to the oil price with a lag of six-to-nine months, with the spot prices in Europe being much lower. Tying the gas prices to oil prices had led to a situation where, in the midst of the world financial crisis, which had precipitated a sharp rise in world oil prices, Europe saw its natural gas prices begin to rise sharply. Little attention was given to the fact that the European spot prices had gone down not only because of the so-called “Shale Gale” sweeping the USA and the ensuing LNG glut in the European market, but also because, due to that crisis, the European spot market was flooded by unclaimed volumes of natural gas, which had been earlier contracted under take-or-pay conditions.

Surprisingly though, immediately following the TEP provisions entering into force, Europeans’ public statements suddenly seemed to change dramatically in favor of Gazprom. However, the desire to get into the Russian gas production industry and to have the pur-chasing prices lowered is still very much an issue.

Also, it could be just a smart move of sorts, given that the measure has already been adopted, while the Europeans still remain in need of building long-term relationships with the Russian gas monopoly. This is particularly true given the sharp changes in the inter-national gas markets caused by the tragedy in Japan and by recent political developments in North Africa.

The first among the Europeans to address the con-ference was the Eurogas President Jean-François Cirelli, head of Gaz de France. He stressed that gas would play an even greater part in the European energy balance in the future, in particular due to further advances in technology. For instance, according to Eurogas fore-casts, demand for gas in Europe will increase by 14-23 percent by 2030 reaching a volume of 640-690 billion cubic meters of gas, compared to current consumption volumes of 560 billion cubic meters of gas.

These figures from European companies consider-ably exceed the forecast made shortly afterwards by the European Energy Commissioner Günther Oettinger, as part of the presentation of the Russian South Stream pipeline project. “According to different forecasts, by the year 2030, the predicted demand for gas in the European Union will vary between 370 and 600 billion cubic meters of gas per year and is likely to change due to recent events in Japan,” Oettinger said.

Meanwhile, a consensus forecast presented by Gazprom predicts that, by 2020, Europe’s demand for

Page 27: Oil&Gas Eurasia July-August 2011

25

!7-8 !"#$–%&'()* 2011"#$%&'() *&+&

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imported gas is likely to be 380 billion cubic meters of gas, reaching 440 billion cubic meters of gas by the year 2030.

Russian Deputy Energy Minister Anatoly Yanovsky was quick to note the considerable difference in the gas demand volume estimates saying that Russia and the EU had agreed to come to an agreement of opinion and to compare notes and verify calculations.

Quite predictably, however, the main topic of dis-cussion at the conference was the Third Energy Package. As if finally heeding the voices of the European gas consumers who, like Cirelli, had appealed “not to over-regulate” the industry so as not to scare off the inves-tors, Philip Lowe, Director-General of the European Commission’s Directorate-General for Energy stated that investments into the construction of gas pipe-lines needed to be protected. He said that the Third Energy Package was not enough to get European energy markets back to work again. “We need cooperation between suppliers and consumers,” Lowe said, adding that this was “necessary to make sure that investors (into gas pipeline construction projects – editor’s note) be offered sufficient incentives to invest in Europe.”

In his opinion, Russian companies should be invit-ed to participate in the discussion of the TEP provi-sions so that their own proposed models could be put to good use. “This is not an end but only a beginning with a view to spelling out a legal framework (for the application of the TEP provisions – editor’s note),” Lowe said, stressing that TEP concepts should be grasped clearly by all of the market players.

At this point it is worth mentioning that, in Lithuania, both Gazprom and the Germany’s E.ON. have suffered as a result of the application of TEP pro-visions. Both corporations had earlier acquired interest in Lietuvos Dujos (the owner of the country’s gas trunk pipelines – editor’s note), which, in the words of Valery Golubev, Deputy Chairman of Gazprom Management Committee, had started applying the TEP provisions “blindly”, without having any alternative gas delivery options, thus putting both Gazprom and E.ON in dan-ger of losing their investments there.

Philip Lowe stressed that, within the framework of company separation based on ownership, it was neces-sary to make arrangements for a return of investments made earlier by pipeline owners. “This is something that needs to be made quite clear,” he said, adding that “the Third Energy Package is a fairly flexible instru-ment.”

He also predicted that the demand for natural gas would continue to grow and, consequently, efforts would be made to allow investors “to have greater cer-tainty” in the business. Lowe noted that the European Union saw a number of technological and economic obstacles to the wider use of renewable energy sources and spoke in favor of pipeline gas deliveries in parallel with liquefied natural gas. “Whatever the advantages of liquefied natural gas in terms of route diversification, gas delivered by trunk pipelines remains one of the more reliable sources,” he added.

At the same time, Philip Lowe spoke in support of efforts to attract more foreign investments into the Russian gas industry and voiced his opinion that the relationships between gas suppliers and gas consumers

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Page 28: Oil&Gas Eurasia July-August 2011

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#7-8 July–August 2011GAS SUPPLY

Oil&GasEURASIA

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should be built on a basis of long-term contracts that would allow investors to have greater certainty. While saying that, he also added that the spot-price compo-nent should be allowed to have its place, too.

In turn, Golubev said that while in light of the current situation in the world gas market Gazprom had modified some of its gas delivery contracts intro-ducing a spot-price component, on the whole the company was not considering the possibility of estab-lishing the spot price as the basis for its gas price for-mation policies.

This puts Gazprom is a strong position. The international gas market has recently seen some dra-matic changes: Libya had stopped its gas supplies to Europe, while Germany and Italy had given up the use of nuclear power in the wake of the tragedy at the Fukushima Nuclear Plant. According to estimates of the International Energy Agency (IEA), as a result of the earthquake, Japan’s requirements for gas will increase by 11 billion cubic meters. Furthermore, Germany, which now needs to find replacements for its nuclear energy projects, will additionally require a minimum of 16 billion cubic meters of natural gas, compared with its current gas consumption needs. Italy, which had stopped using nuclear power follow-ing the Chernobyl Nuclear Plant accident, has now extended its moratorium on the use of nuclear power in the wake of the disaster in Japan.

The above may be some of the reasons why the EU is now taking a softer approach to the South Stream saying that it will support the project. However, in the words of Günther Oettinger, “Given that the South Stream will cross the European territory, it will have to comply with TEP requirements.”

What makes the process of excluding the South Stream from TEP regulations difficult is the fact that some of the countries across which the pipeline will pump gas have concluded intergovernmental agree-ments with Russia that include an investment protec-tion clause, which is in contravention to some TEP provisions. “Nonetheless, those countries will have to apply their internal market regulations and should harmonize their intergovernmental agreements with the EU legislation. The only practical way of doing that is to conclude an agreement directly at a European Union level,” Oettinger said.

In that case, Russia would have to cancel its bilat-eral agreements and to outline its sensitive issues in a global agreement with the EU. The Russian Energy Minister Sergei Shmatko indirectly confirmed that, saying that Russia had already offered the European Union to conclude an intergovernmental type of agreement that would take into consideration the specifics of large-scale investment projects implemen-tation.

Gazprom and its partners have already succeed-ed in having OPAL, a Nord Stream branch pipeline, excluded from TEP regulation, though no such per-mission was granted to NEL, the second branch pipe-line. Nevertheless, if statements already being made by some European politicians are anything to go by, it might be expected that Russia does indeed have a good chance of achieving the agreements it needs also in respect of the South Stream project.

Page 29: Oil&Gas Eurasia July-August 2011
Page 30: Oil&Gas Eurasia July-August 2011

28 Oil&GasEURASIA

Etienne Bourdelet, head of Shtokman Development AG (SDAG) Drilling Directorate and Anatoliy Verkienko, drilling engineer, discuss how drilling will be per-

formed within the scope of the Shtokman project.Production drilling at the Shtokman field during

Phase I includes several stages, envisaging working at three drilling locations in the range of four kilometers (16 wells initially, with more wells to be drilled later on). Each well will take 100 days to drill, including time for unexpected technical problems and weather.

The Shtokman gas condensate field consists of four productive formations; however, Phase I development envisages developing only two gas formations, J0 and J1, which lie atop each other. At the same time, each separate well will allow extracting gas from only one formation. Once the FID is made, the subsea group must install the subsea templates on a seabed before the work starts. So, after the FID is made in mid-December, as is planned, drill-ing will begin around July 2014.

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DRILLING

Shtokman Drilling:Peculiarities in the Process!"#$%&$ %' ()*+,'%$:*-*.$%%*-)& /#*0$--'

Etienne BourdeletAnatoliy Verkienko

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Page 31: Oil&Gas Eurasia July-August 2011

29

!7-8 !"#$–%&'()* 2011"#$%&'%

!"#$% & '()%($)*'+

Average J1 vertical well depth will amount to about 2,200 meters; at the same time, the average measured depth of wells to this formation will amount to about 3,388 meters. The Shtokman field’s reservoirs have a very good productivity, so the wells will be slightly bigger than usual. They are in the top category regarding their productivity and size; there are probably no more than 50 such wells worldwide. The wells are designed to produce gas for 50 years with minimal intervention.

In the drilling areas, two semi-submersible drilling platforms will be operating at the three drilling centers. Each drilling unit will operate for approximately two years; out of these, of which they will work in parallel for about a year. Due to the climate in the region, the working area of the rig will be closed and heated to temperatures above freezing. The platforms have been specifically designed to have frame reinforcement (armor plating) in the case of collisions with blocks of ice (rated ice cover – no more than 40 percent).

One of the main special features of offshore drilling is the mobility of the rig caused by waves on the sea sur-face. Generally, the rig remains in operation with vertical motion in the range of 1 to 4 meters, and 10-50 meters, or 2-3 degrees of lateral motion. To allow this, the marine riser has a flexible connection with the seafloor marine equip-ment and a heave compensator at the drilling unit.

First, drilling of the vertical section is performed; then, the trajectory gradually increases inclination and enters the productive formation at an angle of practically 80 degrees for the J0 wells, with drilling of a sub-horizontal section (about 88 degrees) for J1 wells. This is achieved by using special drilling and navigation equipment.

Drilling mud – the “blood” of a well – will force the operation of a hydraulic downhole motor, which will rotate a drilling bit (rolling bit or a PDC bit), and will also bring the cuttings to the surface. The downhole equipment has a number of sensors which measure hole trajectory inclination, its drift direction, downhole weight on bit and vibrations, formation density, natural gamma ray level, etc. All that information is sent back to the surface using mud pulse – this technology for measuring various parameters and sending them over a distance is called telemetry. The downhole tools create pressure waves by opening and clos-ing a device, and pressure sensors let us read them so we know what is happening down there. This technology has already been proven in use for about 20 years.

In addition to hydraulic downhole motors brought into operation by the drilling mud, there is a technology called “rotary steerable drilling”. Using this technology, we can control and aim the drilling tools in the direction

0/$%H-E/ ;'"5-4+", #-5 /0A#&/. L&' ,B/;.4 , #'?$/ (+1*&-=H'B */ *+/'@,/;'4-$%&/?4' ' +"@-5-+1 – ,/ ,?-5 5'+- 4"('B ?(,"-<'&, ,/@5/<&/, &- 0/$%H- 50. M ?*+/-(4'+/,"&A /&' 4"(, #4/0A 5/<&/ 0A$/ ;/0A,"4% E"@ , 4-#--&'- 50 $-4 ? 5'&'5"$%&A5 1+/,-&-5 ,5-H"4-$%?4,".

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I,J,*#%.1 K3(,5*$%.= 3- D'($%.C @F+G !"#$% &'()$*$Etienne Bourdelet, head of SDAG Drilling Directorate

Anatoliy Verkienko, drilling engineer,L%4$%$( 3- D'($%.C +%,"-*./ 0$(1.$%1-

Shtokman gas-condensate field is located in the central part of the Russian sector of the Barents Sea 550 km away from Kola Peninsula. By the explored reserves of natural gas Shtokman is now one of the largest fields in the world. Phase One of Shtokman field will be developed with annu-al production of 23.7 bn m3 of gas per year by Shtokman Development AG, a compa-ny created in February 2008, a joint project of three leading world companies Gazprom (51%), Total S.A. (25%) and Statoil ASA (24%).

Page 32: Oil&Gas Eurasia July-August 2011

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#7-8 July–August 2011DRILLING

Oil&GasEURASIA

J/5'5/ E';+",$'#--?('B @"0/=&AB ;,'E"4-$-=, *+',/;'5AB , +"0/41 01+/-,A5 +"?4,/+/5, ?1G-?4,1-4 4-B&/$/E'. */; &"@,"&'-5 «+/4/+&/- 1*+",$.-5/- 01+-&'-». J+'5-&.. ;"&-&12 4-B&/$/E'2, 5/<&/ ? */,-+B&/?4' (/&4+/$'-+/,"4% ' &"*+",$.4% /0/-+1;/,"&'- */ @";"&&/= 4+"-(4/+'', *+' F4/5 ,+"-G-&'- '&?4+15-&4" &- *+--(+"G"-4?., " /4($/&-&'- 4+"-(4/+'' *+/'?B/;'4 ",4/5"4'#-?('. 94" @";"#" ?"5" */ ?-0- ?$/<&". K+/5- 4/E/, ;/*/$&'4-$%&A- 4+1;&/?4' ?/@;"-4 5-?4/-*/$/<-&'- 5-?4/+/<;-&'. – 34/(5"&/,?(/- &"B/-;'4?. , ,A?/('B H'+/4"B, 5"E&'4&/- */$- @;-?% ?$"-0--, ' &",'E"C'. 4+-01-4 *+'5-&-&'. ?*-C'"$%&AB 4-B&/$/E'= ' 5-4/;/,. !/ 4+"-(4/+'2 01+-&'. ,?- <-

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planned from the surface; at the same time, rotation of the tool does not stop, while trajectory changes take place automatically. This is a challenge in itself, and it is also affected by the fact that the Shtokman field is located at a high latitude, so the magnetic field is weaker and naviga-tion there requires the use of special technologies. But we can make the well go the direction we want. Geological conditions in the region are relatively easy, which is to our advantage.

Use of complex computerized equipment requires special personnel training; therefore, we need to have more electronics specialists and fewer electricians on board. Electric power will be generated on board the rig using die-sel engines. Gas will not be used for this purpose.

As far as environmental protection is concerned, it should be noted that reserves in the Shtokman field are mainly dry gas; the field has very little liquid hydrocarbons (condensate). Consequently, massive pollution, like an oil spill, is impossible. Still, the Barents Sea, being an Arctic area, is much more sensitive to pollution, so we know we will have to be more careful than in other places. Compared to other regions of the world, we will bring much more waste to the shore for treatment. The cuttings from the well are disposed overboard in most offshore operations worldwide. In case of Shtokman, except for the first two sections, the cuttings generated will be brought back to shore for treatment.

At the very end of development, when the field becomes depleted, in accordance with the existing requirements of the Russian legislation, the wells must be abandoned by installing a number of cement plugs and mechanical caps. Abandoning the wells will require large expenditures, but in the end the place itself will not be a danger to navigation and so on. Of course, we cannot know how the legislation will change, but every year it tends to demand more all over the world. Yet, even now, we have technical possibility to return the sea bottom practically to the original state and we will do it.

Semi-submersible drilling rig – !

installation of such type is planned to be used at Phase I of Shtokman Project.1#234#+.3/'&5 63.#(&5 !

3)"&'#($& – &'&2#+07'38 3)"&'#($3 4.*-4#2&+&*")5 0)4#29,#(&"9 -25 4*.(#: ;&,< !"#$%&'#()$#+# 4.#*$"&.

Page 33: Oil&Gas Eurasia July-August 2011
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32 Oil&GasEURASIA

Modernization – one of Russian President Dmitry Medvedev!s favorite words – was the leitmotif of the 11th International Exhibition Oil and Gas/

MIOGE 2011 and the 9th Russian Petroleum and Gas Congress/RPGC 2011, held in Moscow, which were attend-ed by more than 36 companies from 1,000 countries.

“The Russian energy sector cannot do without upgrades, and thus, without building more facilities for processing petroleum products to turn them into better ‘light! grades,” Sergei Kudryashov, Deputy Energy Minister of Russia, said in his opening address to Congress.

According to Kudryashov!s estimates, the energy sec-tor needs investments of 150 billion rubles over 10 years.

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MIOGE 2011: Fuel and Energy Sector Under Revamp

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“A lot of ‘virtual stocks’ have emerged,” said Gennady Schmal, head of the Oil Producers Union, “and this does not reflect the true state of affairs in the industry.”

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Page 35: Oil&Gas Eurasia July-August 2011

33

!7-8 !"#$–%&'()* 2011"#$%&'(

!"#$% & '()()*+,'-

Plans are underway to create six oil and gas clusters in vari-ous parts of the country. “If all these petrochemical projects materialize, the annual contribution to the GDP will be 650 billion rubles,” Kudryashov said in his remarks.

Much in need of modernization, the Russian fuel and energy sector is promising broad prospects for foreign companies.

This year, the exhibition was attended by dozens of foreign companies, including well-known players such as Caterpillar, CNPC, GE, National Oilwell Varco, Schneider Electric and Siemens.

And their Russian counterparts are not lagging behind the foreigners. The stands of the leading Russian compa-nies, such as Gazprom, Rosneft, Bashneft, Gazprom Oil, Zarubezhneft, Tatneft, Transneft, were impressive.

According to the organizers, more than 20,000 spe-cialists visited the exhibition over four days. Although the conclusion of a breakthrough agreement at the exhibition is a rarity, experts say that the availability of such a unique arena helps them best find business partners.

“The exhibition is a unique opportunity for negotia-tions. People come, friends and strangers: purchasing man-agers, sales managers, production engineers, who carefully inspect the die molding; the top people at large enterprises come,” Alexei Haryushin, head of the Chelyabinsk Forge -and-Press Factory (CHKPZ) said sharing his impressions about MIOGE on the company’s web-site. Participation in the exhibition brought some good results – CHKPZ suc-ceeded in making 135 contracts.

For Russian manufacturers, the exhibition offered an opportunity to discuss the situation about protecting intel-lectual property and the problems of counterfeit equip-ment. During the conference, as part of the Mechanical Engineering Exhibition, GMS – one of the largest pump manufacturers on the Russian market – presented a report on the subject.

Many people worry about the problem of protecting one’s good name and brand from fakes and low quality produce flooding the market: “Sometimes you have to com-pete with companies that manufacture their products liter-ally in the gutter,” one exhibitor who represented Russian manufacturers complained to OGE.

Relevant topics of the oil and gas sector development were discussed during the Enerkon-2011 conference orga-nized with the support of the Ministry of Energy and held within the framework of the exhibition.

The main topic of the conference was innovation. In the participants’ opinion, the problems experienced by basic science do not allow any precise predictions, although the ageing fields are no longer able to meet the market needs.

“A lot of ‘virtual stocks’ have emerged,” said Gennady Schmal, head of the Oil Producers Union, “and this does not reflect the true state of affairs in the industry.”

“The level of control over the Russian energy sec-tor is very low,” Schmal said assessing the situation in the industry with obvious sadness. The former deputy minister in charge of construction of Soviet oil and gas industry enterprises tried to appeal from the rostrum to a more sober assessment of oil reserves, currently often assessed “without leaving one’s PC”. The views of professionals and industry experts were taken into account in the final con-ference resolution sent to the government.

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34

#7-8 July–August 2011EVENT

Oil&GasEURASIA

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Government officials, experts and oil companies may be able to reach a better understanding following the establishment of the Russian Institute of Oil and Gas (RING), whose roadshow at MIOGE was successful.

“I hope the Institute becomes a convenient venue for both science and the state,” Mikhail Silin, Vice-Provost for Strategic Development of the Gubkin Russian State University of Oil and Gas, said expressing his hope. As part of the institute established in May at the suggestion of Deputy Prime Minister Igor Sechin, the national library of the FES will be set up, as well as a social network where researchers can exchange academic ideas both among themselves and with business representatives. The institute will include 10 major Russian profile universities, including the famous Gubkin University, and the Siberian Federal University.

Meanwhile, according to Silin, science and business do not always find a common language in the oil and gas industry: “The scientific community cannot see the big pic-ture – what will businesses pay for?” he complained.

John Pike, International Sales Manager, Eastern Hemisphere !

(in the center) and Ildar Zubairov, Sevice Engineer (left), Lufkin Automation, talk about well automation issues with a visitor.

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Head of VZBT Moscow office, member of the board Dmitry !

Sinyukov (right) and VZBT Trading House director Viktor Popov dis-cuss business issues during MIOGE.

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Page 37: Oil&Gas Eurasia July-August 2011
Page 38: Oil&Gas Eurasia July-August 2011

36 Oil&GasEURASIA

In early 2000, the Republic of Kazakhstan adopted a policy of industrial and

innovative development aimed at weaning the country off its dependence on the sale of raw materials. Much has been done since then: the Sovereign Wealth Fund Samruk-Kazyna was set up to ensure economic stabil-ity, legislation was improved, institutions and organizations emerged to coordinate the actions of businesses and gov-ernment, and small and medi-um enterprises were expanding and so on.

But no one is immune to mistakes, especially the emerg-ing markets. As usual, there was a redistribution of investment and labor resources into the commodity sector. Businesses were focused on earning easy profits and lost interest in man-ufacturing innovative prod-ucts. Meanwhile, the global cri-sis made adjustments reflecting the harm in such trends. Now it has become clear that time was lost, and Kazakhstan has no future without industrial-ization.

This is how the State Program for Accelerated Industrial-Innovative Development of the Republic of Kazakhstan was cre-ated and approved by presiden-tial decree over a year ago. The main idea behind the paper is that for the small amount of time left until 2015, Kazakhstan will have to begin manufacturing innovative products of the second and third technological process stage while leaning on its raw materials sector. Creation of a service industry is assumed through the already established connections, for example, between the representatives of petroleum com-panies and machine toolers. Special clusters are to be built around specific commodities businesses for the medium and small businesses.

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MARKETS

Kazakhstan Corrects Its Mistakes !"#"$%&"' (")*&"+& '", *-.)/"0.

Aider Kurtmulayev !"#$% &'%()'*+$,

Aider Kurtmulayev is a professional journalist and an !

expert on Kazakhstan's oil and gas sector. Kurtmulayev heads the Moscow representation office of the Asia advertising and news agency, which provides services for entering the Kazakh market (www.asiapress.ru).

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37

!7-8 !"#$–%&'()* 2011"#$%&

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This is especially impor-tant in light of the fact that the global economic crisis has almost left Kazakhstan's oil and gas complex unaffected. The industry’s inertia showed in projects that take years, or even decades to complete. Today, the oil and gas complex faces two important challeng-es: to maintain the stability of its development and at the same time become an engine for industrialization of the entire country.

The Program for the Development of Oil and Gas Sector in the Republic of Kazakhstan for 2010–2014 must become a guide for action. More than $34 billion are to be allocated for implementing the program – a truly huge sum of money. Suffice it to say that the industry received only 87 billion dollars over the past twenty years.

By 2014, oil production in Kazakhstan will have grown to 85 million tons per year, while natural gas volumes will be around 54 billion cubic meters a year.

Production will be enhanced by the addition of more commercial production fields in the Tengiz and Karachaganak regions, as well as by the implementation of projects located in the Kazakh sector of the Caspian Sea at the Kashagan field. The country’s leadership is determined to make the national JSC NC KMG the locomotive behind the development of the oil and gas sector. Its will focus on increasing the share of the government involvement in the production of hydrocarbons, direct participation in large-scale oil and gas projects and completion and start-up of new deposits, financing and performance of geological survey works.

The drafters of the program have paid particular attention to oil exports and the enhancement of oil export capacities, as Kazakhstan intends to sell 75 million tons of oil in 2014. Annually, oil production will increase by 8-10 percent and, according to the most conservative forecasts, will amount to 135 million tons per year in 2018. However, it will not peak up until the huge Kashagan field is brought into production.

Diversification of Supplies to Ward Off Global Crises

Today several oil pipelines cross Kazakhstan: CPC, which belongs to Caspian Pipeline Consortium, Atyrau – Samara, Shymkent – Omsk, and Kazakhstan – China (Atasu – Alashankou).

The first and the largest hydrocarbon mainline pipe-line is the line pipe of the Caspian Pipeline Consortium (CPC). Last year, it exported about 30 million tons of oil. Built ten years ago, today the pipeline is a priority route for the export of raw hydrocarbons. The pipe was laid 1,500 km from the Tengiz field in Kazakhstan to the oil termi-nal located in the Black Sea near Novorossiysk. Recently, the consortium made the decision to increase the CPC throughput capacity by building an extension for up to 67

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million tons per year, of which 53 million will be provided by Kazakhstan.

The Atyrau – Samara export pipeline, the second in terms of capacity and importance, was built during the Soviet period. Last year, almost 20 million tons of crude was pumped through it.

About 8 million tons of oil were shipped through the 962-kilometer long Chinese route (Atasu – Alashankou) last year. The Kazakh Government and its Chinese partners plan to imple-ment the second phase of the project – the construction of yet another line that will make it possible to double the main pipeline’s capacity. Under the project, the Kenkiyak – Kumkol, Kumkol – Karakoin – Atasu, and Kenkiyak – Atyrau sections will be built and upgraded.

The country’s government also has plans for the export-oriented Kazakh Caspian Transportation System. The KCTS is designed to ship crude from the major oil fields of Kashagan and Tengiz by barge across the Caspian Sea and then via the Baku – Tbilisi – Ceyhan pipeline to European markets. This route will include the Yeskene – Kuryk pipe-line and an oil-loading terminal, tankers and connecting facilities located on the Baku coast.

Kazakhstan does not have any significant reserves of natural gas, that is why it basically handles gas transit. Gas is transported across the country via the following pipelines: Central Asia – Center (Russia), Bukhara – Urals, the Bukhara Gas Bearing Province – Tashkent – Bishkek – Almaty, Orenburg – Novopskov and Turkmenistan – Uzbekistan – Kazakhstan – China. The latter is of particu-lar importance, since it allows operators to diversify gas supplies to the East. The second stage of its development will be the construction of the Beineu – Bozoy – Akbulak segment. Kazakhstan, Russia and Turkmenistan also plan to build the Caspian Sea Gas Pipeline.

Refineries Upgrade Makes the Agenda One of the key points of the government program

for the forced industrial and innovative development will be the refurbishment and upgrade of all three Kazakh oil refineries. In 2014, they plan to process up to 15 million tons of raw stuff with the conversion depth of 87-90 percent and the fuel quality conforming to European standards.

Today, the Atyrau Refinery produces five million tons of oil per year with the depth of conversion processing at 53 percent. The refinery is more than 70 years old. It oper-ates a number of units related to the primary distillation of crude oil and primary distillation of crudes with the vacu-um unit, as well as catalytic reforming, delayed coking and petroleum coke calcining unit. There are the combination hydrotreatment unit for various fuel types, the sulphuric mass production unit, the hydrogen treatment and produc-tion unit.

The Pavlodar Petrochemical Plant built in 1978 refines about 6 million tons of fuel per year. Siberian oil is supplied

Today several oil pipelines cross Kazakhstan: CPC, !

which belongs to Caspian Pipeline Consortium, Atyrau – Samara, Shymkent – Omsk, and Kazakhstan – China (Atasu – Alashankou).

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!7-8 !"#$–%&'()* 2011"#$%&

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to the refinery, for which purpose the Omsk – Pavlodar pipeline is used. The refinery includes two sectors. The first sector performs the atmospheric distillation and catalytic feedstock reforming. It also operates the gas oil hydrotreat-ment and gas fractionation units. The other one employs the crude vacuum distillation and hydrofining of vacuum gas oil, and the catalytic cracking units and gas fraction-ation units are used.

The “youngest” Shymkent refinery was commissioned back in 1985. It produces about 6 million tons of fuel per year. Today, the plant provides more than a third of petro-leum products in Kazakhstan. It has the electrical desalt-ing plant and atmospheric distillation of crude into the straight-run fractions. In addition, catalytic reforming is carried out with the preliminary hydrotreating of crude oil to obtain high octane gasoline and hydrogen-bearing gas. Fuel hydrowaxing and gas fractionation units are opera-tional. The refinery provides vacuum distillation of fuel oil, and tar visbreaking.

The Plans to Develop Petrochemical Industry The development of petrochemical industry will pro-

ceed in one of two ways. The first is a technical path, aimed at refurbishing and upgrading facilities. The vacuum unit and delayed coking unit will be rebuilt at the Atyrau Oil Refinery. This unit will also have some production com-plexes to produce aromatic hydrocarbons, benzene, 0.1 million tons per year of paraxylene (0.5 million tons per year).

The Shymkent Refinery will start the units for cata-lytic cracking and isomerization, as well as hydrogen, polypropylene, and sulfur production units. The diesel fuel hydrofining units will be upgraded. At the Pavlodar refin-ery, the diesel fuel hydrofining unit will be upgraded, and the units for isomerization and selective desulfurization of gasoline, and for catalytic cracking unit built.

A bitumen plant is proposed to be built on the tech-nical basis of the Aktau Plastics Plant with the capacity of 500,000 tons of road tar per year, as well as construction of the integrated gas chemical complex for the produc-tion of petrochemicals with over 1 million tons per year capacity.

The second trend includes arrangements for the cre-ation of industrial clusters, as the national companies will start opening the new production facilities to ensure the increase in the level of production of the second or third technological process stage, whereas the government will make sure they can be sold.

In addition, contracts will surely include commit-ments to the organization of processing industries and procurement priorities for domestic products. To fulfil the plans for the development of petrochemical production, a special economic zone called the National Industrial Petrochemical Technology Park has been created in the Atyrau region. Small and medium-size companies find the Techology Park especially attractive.

According to the program for industrial and inno-vative development, the results of the effort should include a rise in productivity, development of the national economy and strengthening the role played by small and medium-sized businesses, rational labor man-agement, and the improvement of professional skills. All this is meant to help Kazakhstan join the group of post-industrial nations.

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Page 42: Oil&Gas Eurasia July-August 2011

40 Oil&GasEURASIA

As operators and EPC companies gather at Offshore Europe this year, they will be greeted by a general sense of renewed optimism in the European offshore

oil and gas sector.Few would deny that the last few years have been

something of a rollercoaster ride for the sector with financ-ing difficulties and a low oil price resulting in a number of projects going on hold.

There is also some uncertainty in the future as we wait to see the full extent of the recent Government tax increase on UK production although it will probably take as long as 12 months before we can make a full evaluation. This being said, however, there are positive signs.

Globally, for example, our database EICDataStream which tracks over 8,500 projects in the global energy indus-try is showing Europe leading the way in terms of the number of offshore projects.

Fig. 1, for exam-ple, proves interest-ing reading showing the top 15 countries around the world in terms of number of offshore projects. As one can see, the UK and Norway with 168 and 117 offshore projects respectively are both attract-ing considerable business alongside, other offshore hubs, such as the Gulf of Mexico, West Africa and South East Asia. For the Oil and Gas Eurasia’s readers, it’s also interesting to see that Russia is in 13th place with 30 current offshore projects.

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Renewed Optimism in the European Oil and Gas Sector!"#$%&'()*' +&,-&./0$"1' (&)-$# ( $%-*2*02$2 "(-#&3/&- 45657&&

Mike Major, Chief Executive, EIC (Energy Industries Council) !"#$ !%#&'(), *)+,-&+./ EIC (Energy Industries Council)

Fig. 1. Number of offshore oil and gas projects. !

!"#. 1. $%&"'(#)*% +(,)(-./%*01 23%(4)%* +. 5(&6,(. !

OFFSHORE

Page 43: Oil&Gas Eurasia July-August 2011

41

!7-8 !"#$–%&'()* 2011"#$%&

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The number of projects is, of course, only one search parameter with the value of offshore projects being of par-ticular interest to the energy supply chain that will be at Offshore Europe this year.

To this end, when you look at offshore projects accord-ing to value, there are a number of other countries leading the way, such as Kazakhstan due to the capital inten-sive nature of the Kashagan developments, and Russia because of the large scale investments in the Shtokman and Sakhalin fields (see Fig. 2).

What is clear from this illustration, however, is that Europe is continuing to hold its own with the combina-tion of investments in UK and Norway together amounting to a cumulative higher investment value than any other country.

These encouraging figures are backed up by the 41 members and non-members we will be hosting at the EIC pavilion at Offshore Europe this year, covering many differ-ent facets of the UK offshore supply chain and all looking to tap into new business development opportunities. In total, we believe that our over 600 members, many in the offshore oil and gas sector, generate around £100 billion in revenues from their UK operations alone, although, of course, only a portion of this would be from European off-shore oil and gas projects.

And there is no doubt more investment to come. Oil and Gas UK, the trade association for the UK offshore oil and gas sector, believes that up to 25 billion barrels remain to be won from the UK Continental Self alone and in Norway, there is also significant potential. The Norwegian

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> "#$4'+ *4%$&%6# 2011 :'-% '3S#+ -'3(/) 4 M#4#$,'+ +'$# 2,%/)&#68,' 1,)2)61. "' 1$%4,#,)7 1 &#+ A# "#$)'--'+ 2010 :'-%: "' 1($'; ,#<&) ,% 15,6% ) "' :%25 ,% 17,6%. F' 0'&. 5$'4#,8 -'3(/) "%-%#&, "'&#,@)%6 +#1&'$'A-#,); 4 M#4#$,'+ +'$# 41# #D# 4(1'*.

P&'& "'&#,@)%6 "'-&4#$A-%#&1. ,'4(+) "$'#*&%+), 2%$#:)1&$)$'4%,,(+) 4 3%2# -%,,(0 EICDataStream. K%,,(# "'*%2(4%7&, /&' 4 M#4#$,'+ +'$# $#%6)25#&1. 2,%/)&#68,'# *'6)/#1&4' "$'#*&'4, 14.2%,,(0 1 "'-4'-,'; "#$#$%3'&-*';, '351&$';1&4'+, % &%*A# "'-4'-,(+) &$53'"$'4'-%+) ) "6%&<'$+%+). G16) 4 3%2# -%,,(0 EICDataStream )1*%&8

Fig. 2 Value (US$ million) of offshore oil and gas projects. !

!"#. 2. 7)%"8%#)6 (* 8&+ $ 79:) +(,)(-./%*01 !

23%(4)%* +. 5(&6,(.

Page 44: Oil&Gas Eurasia July-August 2011

42

#7-8 July–August 2011OFFSHORE

Oil&GasEURASIA

Project Name / ;."8(+%*.+"( 23%(4). Dollar Value

(million) / O<(+4. * $8&+

Startup Year / =*%>

* ?4#2&@.).<"AOperator / B2(3.)%3 Tracking Status /

C(4@D"E #).)@#

Black Sea deposits – Tuapsinsky and Zapadno-Chernomorsky (Shatsky Ridge – Western Black Sea License Area) – Val

Shatsky / !+0/()('&+.-1 2+).(3( 4()1 – 56"*0-.0$-# *)(3-7, 8"*"&.(-2+).(4()0$-# 69"0/($ (:"; <"/0$(3( – ;-=+.,-(.."1 (7;"0/> ,"*"&.(# 9"0/- 2+).(3( 4()1)

1 000 2016 Rosneft / «?(0.+@/>» Future /A+)0*+$/-B.C#

Chayvo oil and gas field (Northern Section) / D+@/+3",(B(+ 4+0/()('&+.-+ 2"#B( (E+B+).C# 69"0/($) 1 000 2016 Rosendra / ?(0.+&)" Future /

A+)0*+$/-B.C#Chugoryakhinskoye gas and condensate field /

263()>1F-.0$(+ 3",($(.&+.0"/.(+ 4+0/()('&+.-+ 300 2017 Gazprom / «G",*)(4» Future / A+)0*+$/-B.C#

Diagonalnoye offshore field / H-"3(.";>.(+ I+;>@(B(+ 4+0/()('&+.-+ 700 2015 LUKOIL / «JKLMNJ» Future /

A+)0*+$/-B.C#Dolginskoye oil and gas field / H(;3-.0$(+ .+@/+3",(B(+

4+0/()('&+.-+ 500 2016 Gazprom / «G",*)(4» Future / A+)0*+$/-B.C#

Fedinskoye oil prospect (a.k.a. Hjalmar Johansen Ridge)/ O+&C.0$(+ .+@/+3",(B(+ 4+0/()('&+.-+ (F)+7+/

P>1;4")" N(F".0+.")500 2017 Zarubezhneft /

«8")67+'.+@/>»Future /

A+)0*+$/-B.C#

Kamchatka oil deposit / L"49"/0$(+ .+@/1.(+ 4+0/()('&+.-+ 2 000 2014 Rosneft / «?(0.+@/>» Future /

A+)0*+$/-B.C#Khvalynskoye gas and condensate field – Phase 1 /

PB";C.0$(+ 3",($(.&+.0"/.(+ 4+0/()('&+.-+ – @"," 1 5 000 2016 LUKOIL / «JKLMNJ» Future / A+)0*+$/-B.C#

Lagansky oil and gas block – Morskaya discovery / J"3".0$-# .+@/+3",(BC# 7;($ – !()0$"1 0/)6$/6)" 150 2011 LLC Petro Resurs /

«A+/)()+06)0»Future /

A+)0*+$/-B.C#Ludlovskoye and Ledovoye gas fields / J6&;(B0$(+ -

J+&(B(+ 3",(BC+ 4+0/()('&+.-1 2 000 2014 Gazprom / «G",*)(4» Future / A+)0*+$/-B.C#

Ob Bay gas discovery / G",(BC+ ,";+'- M70$(# 367C 100 2011 SEVMORGEO / «E+B4()3+(»

Future / A+)0*+$/-B.C#

Peshanoozerskoye field development / A+09".((,+)0$(+ 4+0/()('&+.-+ 150 2011 Urals Energy / «K)";

Q.+)&'-»Future /

A+)0*+$/-B.C#

Prirazlomnoye oil field / A)-)",;(4.(+ .+@/1.(+ 4+0/()('&+.-+ 2 500 2011

Rosshelf and Gazprom/ «?(0I+;>@» - «G",*)(4»

Active / H+#0/B6RS-#

Sakhalin I – Arkutun-Dagi oil and gas field / «E"F";-. 1» – .+@/+3",(B(+ 4+0/()('&+.-+ T)$6/6.-H"3- 5 000 2014 Exxon Active /

H+#0/B6RS-#

Sakhalin II – Piltun-Astokskoye field – Phase 2 / «E"F";-. 2» – A-;>/6.-T0/(F0$(+ 4+0/()('&+.-+ – @"," 2 19 400 2014

Sakhalin Energy Investment Co. /

«E"F";-. Q.+)&'- U.B+0/4+./»

Active / H+#0/B6RS-#

Sakhalin III – Ayashsky block / «E"F";-. 3» – T1I0$-# 7;($ 3 000 2015 Gazprom / «G",*)(4» Future / A+)0*+$/-B.C#

Sakhalin III – Kirinskoye field (Kirin block) / «E"F";-. 3» – L-)-.0$(+ 4+0/()('&+.-+ (L-)-.0$-# 7;($) 1 000 2012 Gazprom / «G",*)(4» Active /

H+#0/B6RS-#

Sakhalin III – Veninsky and Kirinsky blocks / «E"F";-. 3» – :+.-.0$-# - L-)-.0$-# 7;($ 5 000 2012

Rosneft and Sinopec/ «?(0.+@/>» -

Sinopec

Future / A+)0*+$/-B.C#

Sakhalin III – Vostochno-Odoptinsky block (East Odoptu) / «E"F";-. 3» – :(0/(9.(-M&(*/-.0$-# 7;($ 3 000 2015 Gazprom / «G",*)(4» Future /

A+)0*+$/-B.C#

Sakhalin IV – Lopukhovsky block / «E"F";-. 4» – J(*6F(B0$-# 7;($ 13 100 2016

Gazprom Neft (formerly Sibneft)/ «G",*)(4 .+@/>»

(7CBI. «E-7.+@/>»)

Future / A+)0*+$/-B.C#

Sakhalin V – East Schmidt block (Vostochno-Shmidtovsky) / «E"F";-. 5» – :(0/(9.(-<4-&/(B0$-# 7;($ 5 000 2015 Rosendra / ?(0.+&)" Future /

A+)0*+$/-B.C#

Sakhalin V – Kaigansky-Vasukansky block / «E"F";-. 5» – L"#3".0$(-:"0R$".0$-# 7;($ 5 000 2016

Elvary Neftegaz (consortium of BP and

Rosneft) / «Q;B")- .+@/+3",»

Future / A+)0*+$/-B.C#

Sakhalin VI – Pogranichny block / «E"F";-. 6» – A(3)".-9.C# 7;($ 2 000 2018 Petrosakh /

«A+/)(0"F» Future /

A+)0*+$/-B.C#

Page 45: Oil&Gas Eurasia July-August 2011

43

!7-8 !"#$–%&'()* 2011"#$%&

!"#$% & '()#'()*+,

Sanarskoye, Lisovskoye oil and gas fields / E".")0$(+ - J-0(B0$(+ .+@/+3",(BC+ 4+0/()('&+.-1 800 2016 Rosneft / «?(0.+@/>» Future /

A+)0*+$/-B.C#

Shtokman Gas Field (Shtokmanovskoye) – Phase 1 / </($4".(B0$(+ .+@/+3",($(.&+.0"/.(+

4+0/()('&+.-+ – @"," 115 000 2018

Shtokman Development AG (JV of Gazprom; Total; Statoil)/«</($4".

H+B+;(*4+./ TG» (EA «G",*)(4"», Total,

Statoil)

Future / A+)0*+$/-B.C#

Shtokman Gas Field (Shtokmanovskoye) – Phase 2 and 3 / </($4".(B0$(+ .+@/+3",($(.&+.0"/.(+

4+0/()('&+.-+ – @"," 2 - 35 000 2018 Gazprom / «G",*)(4» Active /

H+#0/B6RS-#

Temryuksko-Akhtarsky Block Exploration – Azov Sea / ?",B+&$" ." 5+4)R$0$(-TF/")0$(4 7;($+ – T,(B0$(+ 4()+ 100 2015

Priazovneft Oil Company (JV of Rosneft, LUKOIL,

Krasnodar Regional Administration) / DL

«A)-",(B.+@/>»

Future / A+)0*+$/-B.C#

Tsentralnoye offshore oil and gas field / !()0$(+ .+@/+3",(B(+ 4+0/()('&+.-+ V+./)";>.(+ 200 2015

Gazprom, LUKOIL and KazMunaiGaz (KMG) / «G",*)(4» «JKLMNJ» - «L",!6."#G",»

(L!G)

Future / A+)0*+$/-B.C#

Vladimir Filanovsky oil field (Yuzhno Rakushechnaya structure) / D+@/1.(+ 4+0/()('&+.-+ :;"&-4-)" O-;".(B0$(3( (W'.(-?"$6I+9."1 0/)6$/6)")

5 000 2015 LUKOIL / «JKLMNJ» Future / A+)0*+$/-B.C#

Yamal Peninsula oil and gas developments (Nadym, Bovanenkovskoye, Yuzhno-Russkoye, Kharasaveiskoye,

Kruzenshternskoye, Kamennomysskoye, and Obskoye gas condensate fields) / !+0/()('&+.-1 ." *-(B+ X4";

10 000 2019 Gazprom / «G",*)(4» Future / A+)0*+$/-B.C#

Page 46: Oil&Gas Eurasia July-August 2011

44

#7-8 July–August 2011OFFSHORE

Oil&GasEURASIA

),<'$+%@)7 "' &#*5D)+ "$'#*&%+ "'-4'-,(0 $%2$%3'-&'*, '15D#1&46.#+(0, ,%"$)+#$, 4 G4$'"#, &' ,%;-#&1. 202 -#;1&457D)0 ) 35-5D)0 "$'#*&%.

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?,':)# +#1&'$'A-#,). M#4#$,':' +'$. 0%$%*&#$)-257&1. 4(1'*)+ -%46#,)#+ ) &#+"#$%&5$%+), 1&%3)68-,(+ $)1*'+ '3$%2'4%,). *'$$'2)), :)-$%&'4, "$'$(4%+) 4'-( )6) "#1*% 4 1*4%A),5. R'9&'+5 1#:'-,. *'+"%,).+-'"#$%&'$%+ ,#'30'-)+( ,%-#A,(# ) &'/,(# -%&/)*) ) BOR, 1"'1'3,(# -#1.&)6#&).+) '3$%3%&(4%&8 -%,,(# 4 $#A)+# $#%68,':' 4$#+#,).

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Energy Industries Council (EIC) – 4#-5D## '&$%16#4'# '3S#-),#,)# 3$)&%,1*)0 *'+"%,);-"'1&%4D)*'4 "$'-5*-@)) ) 5165: 4 +)$'4'+ 9,#$:#&)/#1*'+ 1#*&'$#. F% 4(1&%4-*# Offshore Europe 5 EIC 1%+(; 3'68='; 1&#,- (B64, 2%6 3). F% 1&#,-# 35-#& "$#-1&%46#,% 41 *'+"%,)., *%* /6#,(, &%* ) :'1&) EIC.

> 0'-# 4(1&%4*) EIC "6%,)$5#& $%1"$'1&$%,.&8 «L5*'4'-1&4' "' +%&#$)%68,'-&#0,)/#1*'+5 1,%3A#,)7 EIC – 2012», % &%*A# 2%"51&)&8 ,'4(; 1#$4)1 EIC Consult, 36%:'-%$. *'&'$'+5 +'A,' "'65/%&8 '32'$( ' 1'1&'.-,)) $(,*% ), "' "$#-4%$)&#68,'+5 2%*%25, *',1568&%@)-',,(# 5165:) ) 5165:) "' )116#-'4%,)7 $(,*% ) $%24)-&)7 3)2,#1%.

Petroleum Directorate (NPD) estimates that 50 percent of oil remains in place on the Norwegian Continental Shelf with the volume of undiscovered resources estimated by the NPD at 2.6 billion standard cubic metres of oil equiva-lents.

While production in the North Sea is dropping with Q1 2011 showing a significant decline of 15.6 percent in crude oil and 17.6 percent in gas compared to the same period in 2010, there is still all to play for in the North Sea’s fields.

This potential is manifesting themselves in a number of new projects with EICDataStream pointing to a consid-erable number of subsea processing, subsea tiebacks, subsea pipelines and platform projects throughout the North Sea. If you search EICDataStream under current subsea develop-ment projects across Europe, for example, 202 current and future projects are found.

Having been in production for more than 40 years, the North Sea is today one of the world’s most innovative off-shore locations where older infrastructure from the 1970’s and 1980’s is now functioning alongside some of the latest new technologies and a host of smaller operators who are looking to make older and smaller fields more economi-cally viable.

The result is an increased focus on reservoir monitor-ing technologies to ensure wells are performing at opti-mum performance, a growth in multilateral wells, complex subsea systems, and a growth in technologies, such as sub-sea tiebacks, which tie in newer fields to established infra-structure as well as minimising platform requirements.

Many of the North Sea’s fields are also defined by high pressures and temperatures with the regular dangers of corrosion, hydrates, sand and water breakthrough. Against this context, operators today need to develop reliable and accurate gauges and instruments, which can generate real-time data for quite literally decades.

Finally, there is an increased focus on enhanced oil recovery (EOR) techniques in the North Sea sector with Statoil, in particular, considered an industry leader, with an ambitious recovery goal of 55 percent for its subsea operated fields and 65 percent for platform operated fields.

This breadth of technologies is well represented in the wide variety of companies we will be hosting at Offshore Europe this year, covering everything from valve and power specialists, process technologies to help with the treatment of increasing water cuts, anti-corrosion providers, fibre optics solutions and the latest safety equipment (among many others).

From remote and geologically complex reservoirs to the need to increase production and maximise investments from offshore assets, European operators are looking to new technologies like never before. With prospects for the offshore European sector looking encouraging, Offshore Europe is likely to prove to be a busy few days.

The Energy Industries Council (EIC) is the leading trade association for UK companies that supply capital goods and services to the energy industries worldwide and will be hosting of 41 of its members and non-mem-bers at Offshore Europe in the event’s largest pavilion at stand B64 in Hall 3.The EIC will also be launching the EIC Procurement Guide 2012 at the event as well as EIC Consult, a new service which will provide market reports and bespoke consultancy, market research and business development services.

Page 47: Oil&Gas Eurasia July-August 2011
Page 48: Oil&Gas Eurasia July-August 2011

46 Oil&GasEURASIA

As operators and EPC companies gather at Offshore Europe this year, there will – as always – be a dazzling array of reservoir monitoring technologies on display,

claiming to provide operators with information on every facet of their offshore production systems.

! "#$% &$'( )$%*+,---$*./+#$/0 - *$'/1'2-)- *$ #.3-,-2.4)-% /+5/+6$#)+%, *$4#+7)+% - (*/+78.,-9 4#/$-#.8:4#7$% (EPC) 7,$7: 74#/.#1#41 ,+ 704#+7).

Offshore Europe, &'., *$ #/+'-;--, 6('.# */.'4#+78., ;.80< 4*.)#/ ,$7.<=-3 #.3,$8$&-< %$,-#$/-,&+ %.4#$/$>'.,-<. ?.3,$8$&-- *$48.',.&$ *$)$8.,-1 /+5/+6$#+,0 4 ;.8:9 */.-'$4#+7-#: $*./+#$/+% ,+-6$8.. *$8,(9 -,@$/%+;-9 $ 74.3 )$%*$,.,#+3 4-4#.%, -4*$8:5(.%03 */- /+5/+6$#). %$/4)-3 %.4#$/$>'.,-<. A+,,0. #.3,$8$&-- $*#-%+8:,$ *$'3$'1# '81 */$.)#$7 7 B.7./,$% %$/., &'. $4,$7,$. 7,-%+,-. ('.81-.#41 ")$,$%-2.4)$< /.,#+6.8:,$4#- 4#+/03, ,.6$8:=-3 *$

Reaching Parts of the Reservoir That Other Technologies Can’t Reach!"#$% &%'(")"*++ ,"-"*.& # /01/02"&3% &/.4("4"5&.,($' .605&3"# -%5&"/"74%(+8

Terje Baustad, Emerson Process Management !"#$" %&'(&), Emerson Process Management

OFFSHORE

Measuring pressure and temperature behind the casing in subsea !

production wells.!"#$%& '"()$*+, + -$#.$%"-/%& ( 0"-%/1*2# .%23-%"*3-($ !

*" .2'(2'*24 35("6+*$.

Page 49: Oil&Gas Eurasia July-August 2011

47

!7-8 !"#$–%&'()* 2011"#$%&

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Such monitoring technologies are particularly perti-nent for the North Sea where the focus on making older and smaller fields economically viable and the need to often navi-gate around or tie into existing subsea infrastructure makes accurate and real-time reservoir monitoring all the more important.

Yet, for all the technology advances and all the bold claims made recently, there still remain areas of the reservoir that operators know remarkably little about. It’s this knowl-edge gap that may account for the widening recovery gaps between topside and subsea wells, with the latter generating average recovery rates of up to 15 percent less than their top-side counterparts.

While the high costs and risk profiles of subsea interven-tion are a major reason for this, another cause is the obstacles to securing reservoir data. Let’s take some examples.

One of the most inaccessible areas in subsea well pro-duction systems today is the annulus of an oil well – the space within the well where fluid can flow with a completed well consisting of two annuli (annulus A and B).

Normally, the annulus would require little of the opera-tor’s attention and in dry wellhead offshore wells can be controlled by valves. Problems occur, however, if there are high pressures further down the well and the cement seals behind the wellbore casing, which protect the annuli, are of poor quality.

In such instances, high pressures in the annulus B can lead to deteriorating cement sealing, casing collapse, and oil or gas migrating vertically towards the surface – potentially very hazardous. A number of oilfield services companies have previously written about these difficulties particularly in High Pressure/High Temperature areas of the North Sea, the Elgin

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#7-8 July–August 2011OFFSHORE

Oil&GasEURASIA

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and Franklin fields on the UK Continental Shelf (UKCS) being one such example.

Yet, while regular monitoring of pressures and tempera-tures in the annulus B could provide early warnings and allow remedial action to be taken, operators can’t access such infor-mation following completion, due to the sealing and cement-ing of the casing.

The result is a real information gap in operator infor-mation on subsea production and a very understandable tendency to be overcautious in regard to decisions over the dimensioning of casing and the shutting in of wells. This inability to verify barrier integrity can potentially cost the operator millions of dollars and certainly affect recovery rates.

Another example of the subsea information deficit is in the areas of corrosion and sand erosion. Both sand and corro-sion reduce the life of offshore production and storage equip-ment, eroding completion components, impeding wellbore access and interfering with downhole equipment.

Yet, while sand and corrosion monitoring technolo-gies have made significant advances over the last few years (Emerson has a long history of sand erosion monitoring in the North Sea with the Sleipner field being a recent example), there still remain areas of the reservoir that they struggle to reach. This is due to most current solutions being wireline-based with the need for accompanying cables, power and other subsea infrastructure. The result is restrictions as to areas of the reservoir they can cover.

Finally, there is the continued lack of information on flow rates downhole in the reservoir. While topside and subsea multiphase meters today are providing operators with a more accurate understanding of flow regimes, such information tends to dry up the further you go downhole.

This has been exacerbated by the growing complexity of well architecture with multilateral wells, where multiple wells are drilled from a single main wellbore, increasingly common as operators looking to reduce completion work, and the number of production well slots and wells drilled. Multilateral wells are particularly common in the North with Statoil’s Glitne field, Shell’s Term field being two of many examples.

However, the ability to access flow rates from different zones and branches from a multilateral well to date remains elusive with operators settling on total production flow data rather than flow from specific well zones and further down-hole. Again, operators are missing out on vital information that could have a key input into future production and reser-voir management decisions.

A recent study conducted by Emerson of an actual offshore platform with about 4,000 I/O found that installing wireless along with other technologies in the process control systems can realize savings of up to 7 percent, or more than $1 million.

!"#$%&"" '(()"#*%$&'", +,*%"#"&&*" -*.+$&'-"/ Emerson &$ #"/(0%123"/ .*,(-*/ +)$04*,-." (*-*)* 4 000 0*5"- %%*#$/%6%*#$), +*-$7$)*, 50* 1(0$&*%-$ 8"(+,*%*#&69 1(0,*/(0%, &$,:#1 ( '(+*);7*%$&'". #,1<'9 0"9&*)*<'/ % ('(0"." 1+,$%)"&': +,*="(($.', .*>"0 (?-*&*.'0; #* 7% ')' 8*)"" $1 .)&.

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49

!7-8 !"#$–%&'()* 2011"#$%&

!"#$% & '()#'()*+,

So how can the information gap be closed?The good news is that the technologies are already here

to take operators into areas of the well and subsea production systems that were previously considered inaccessible.

Wireless technologies, for example, are having major impact on the offshore sector, allowing operators to add mon-itoring points throughout their offshore facilities at a fraction of the cost of wired instrumentation and with the added ben-efit of reduced deck space.

A recent study conducted by Emerson of an actual off-shore platform with about 4,000 I/O found that installing wireless along with other technologies in the process control systems can realize savings of up to 7 percent, or more than $1 million.

At Offshore Europe, visitors will have the opportunity to see how Emerson is adapting its wireless technologies and taking them further subsea in generating temperature and pressure information from within the well casing and Annulus B.

The same focus will also be seen downhole where our focus will be on generating multiphase measurements of frac-tions and flow rates from either single bore or multilateral well configurations downhole in the reservoir. Such a development will be key to operators’ understanding of the reservoir flow and zonal contributions from specific wells.

If one is to ensure the seamless and cost effec-tive transfer of hydrocarbons from reservoir to refinery and maximize investment returns from offshore assets, operators need greater control and more information on their production operations. At Offshore Europe this year, we’ll be able to see how technology providers are rising to the challenge in closing this subsea information gap further.

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50 Oil&GasEURASIA

Prediction and delineation of hydrocarbon accu-mulations’ migration pathways and formation areas is impossible without the application of the

geosoliton concept. This concept amplifies the exist-ing research areas with the mechanism of physics of dispersed, gaseous, and liquid materials migration pro-cesses that opens up new ways and approaches to the prospecting, exploration, and development of oil and gas fields. This article examines one example of such manifestations of active degassing and geosoliton activ-ity in Western Siberia.

Manifestations of interior geodynamic activities are closely tied to the sedimentation processes of sedimen-tary rock formation, to the distribution therein of sandy-argillaceous material, and to the post-sedimentation processes of local geotechtonics and fluid dynamics up to recent time. The study of focal points and areas of geodynamic activity and fluid migration may pro-vide highly useful information regarding the nature of a given hydrocarbon reservoir as a whole. Long-term geological, geophysical, and geochemical observations and studies of the recent geodynamic activities in oil-and-gas-bearing territories at special geodynamic test-ing sites focalized in areas, which differ in terms of their geological structure, have made it possible to ascertain the unity of fluid systems generating mineral deposit fields as well as their close ties with the deep-seated faults and with the processes of degassing of the Earth’s interior spheres [1].

Contingency has been established between hydro-carbon accumulations and the more actively developing deep-seated faults whose dynamics are manifested in the high-gradient recent vertical and horizontal movements of the Earth’s surface and temporal changes in geo-physical fields. Geochemical studies have identified fluid systems migrations in the basement of the sedimentary mantle and near its surface.

What is beyond doubt is that high permeability rock is associated with the areas of recent seismic instability. The spatial geometry of manifestation of such processes

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EXPLORATION

The Geosoliton Component in the Prediction and Delineation of Oil and Gas Deposits!"#$#%&'#(()* $#$')+%*,-)* ./& ./#0(#1" & 2)/'&/#+)(&& 1)%"3"4 ("5'& & 0)1)

Vladimir Megerya, Sergei Bembel !"#$%&%' ()*)'+, ,)'*)- .)&/)"0

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51

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is, more often than not, of a focalized near-vertical nature, rather than strictly linear-planar nature [1]. Recent deep-earth geodynamic and fluid dynamic pro-cesses define the focal-point nature of hydrocarbon gen-eration and tend to generate oil and gas deposits with a great variety of forms and phase correlations.

The current accumulated data regarding the geody-namic and hydrodynamic characteristics of the subsur-face of the Western Siberian oil-and-gas bearing basin and regarding the location of the fields makes it pos-sible to state that the responsibility for the formation of hydrocarbon accumulations lies with the processes of degassing of the Earth [1].

The geosoliton concept [1] provides practically all necessary mechanisms and explanations both for the focal points of oil-and-gas generation of certain compo-nents of oil, as a whole, and for the likely hydrocarbon migration pathways in distinctive vicinity of such focal points. The physical nature of geodynamic emissions is such that, above the rock-breakdown central focal points, essentially, temporary local attenuations appear in the gravitational field as well as higher-than-normal thermal and electromagnetic activities. It is in this interval, on the border between the Earth’s crust and the atmosphere, that particular conditions emerge to allow for sedimentation. The geodynamic activity of the interior geospheres impacts not only the geotectonic phenomena but also the nature of sedimentary material distribution during the sedimentation period.

Manifestations of geodynamic activity, including neotectonics, associated with the processes of geosoli-ton-like degassing of the Earth and fluid dynamics, are linked to the so-called rock formation breakdown zones (dynamically stressed zones, deconsolidations, reduced zones, etc.). Such near-vertical geological features, which are called near-vertical breakdown zones [1], near-verti-cal geological bodies, dynamically stressed zones, etc., each having its own interior structure but sharing some common typical characteristics, can be identified and mapped in most of the oil-and-gas bearing regions of Western Siberia, Russia, and the world as a whole.

In the magnetic and gravitational fields, the mosaic structure of such geodynamic focal points of energy and matter emissions manifests itself quite unambiguously on the continents and in the oceans, including all “oce-anic mountain ranges”. Throughout that three-dimen-sional mosaic, there are predominant focalized areas with higher of lower concentrations of discrete small-scale positive or negative anomalies. The axial regions of such geological features as well as of the focal points of geodynamic activity and of fluid/gas migrations, which

About the !uthors / "#$%$&'( )* +#,)-+.Sergei Bembel, Candidate of Geological and Mineralogical Sciences, Associate Professor, Department for Petrolium Field Geology, Tyumen State Oil and Gas University.)&/)"0 ,)'*)- 12/)'324%5, 6.*.-&.7., $28)73 6#9)$': ;'2&:<"242- *)2"2*%% 7)93% % *#=#, >?&)7<6%- *2<@$#'<34)77:- 7)93)*#=24:- @7%4)'<%3)3

Vladimir Megerya, Candidate of Geological and Mineralogical Sciences, Vice President for Geophysics, GEOTECH Holding()*)'+ !"#$%&%' (%A#-"24%5, 6.*.-&.7., 4%8)-;')=%$)73 ;2 *)29%=%6) BCD «EFD>FG H2"$%7*»

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#7-8 July–August 2011EXPLORATION

Oil&GasEURASIA

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

? (#%1,-1'' $,#3#6'*#%%#/ 8,$)&)1'' %)>#8'* #:I-53%,%', ' 0,*#8 $)&#+9> *".:, '3-#6=&.,09/ 865 +98,6,-%'5 &#% +,"*'()6=%#/ 0'$")1'' D? [3], 8'44,",%1')1'' -"#+#85<'> ' %,-"#+#85<'> ")&6#0#+. !# #-",8,6,%'; [2, 3], %)6'2', '6' #*3.*3*+', $)&#+9> *".:, '> 4#"0), -"#*57,%%#3*= ' '3*#2%'( +#&%'(%#+,%'5 + 3##*%#C,-%'' 3 6#+.C()0' D? -#&+#65,* (6)33'4'1'"#+)*= -#36,8-%', -# -"#8.(*'+%#3*' ' -,"3-,(*'+%#3*'. B3>#85 '& $,#3#6'*#%%#/ (#%1,-1'', %,#:>#8'0#/ -",8-#396(#/ 865 #:")&#+)%'5 «$)&#+9> *".:» 5+65,*35 3.<,3*+#+)%', "58#0 )(*'+%#$# $,#8'%)0'2,3(#$# #2)$) ' 36,83*+'5 ,$# -"#5+6,%'5 – &#%9 8,3*".(1'' (()( -")+'6#, 3.:+,"-*'()6=%#/). A*,-,%= %)".C,%%#3*' -#("9C,( + ")/#%, #2)$) :.8,* #-",8,65*= 3*,-,%= 3#>")%%#3*' &)6,7,/, ) +,"*'()6=%)5 +9")7,%%#3*= #2)$) 8,3*".(1'' – +,"#5*-%9/ H*)7 %,4*,$)&#%#3%#3*'. F)6'2', $)&#+9> *".: ' VAMP-3*".(*." ")330)*"'+),*35 + 6'*,")*.", [2, 3] ()( )*"':.* %,4*,$)&#%#3%9> :)33,/%#+ 3 )(*'+%90 46;'-8#8'%)0'2,3('0 ",7'0#0, ) *'-9 $)&#+9> +93)2'+)%'/, 4'(3'".,09, -# 8)%%90 3,/30#")&+,8(', -#&+#65;* 3.8'*= # -"#1,33)> 4#"0'"#+)%'5 '6' ")&".C,%'5 &)6,-7,/ D?, # -"#8.(*'+%#3*' *,> '6' '%9> 6#+.C,( D?. M*# +-#6%, 3##*+,*3*+.,* -"'%1'-)0 $,#3#6'*#%%#/ (#%-1,-1'' 8,$)&)1'' @,06' [1].

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have the shape of near-vertical chimneys, find their manifestations in the form of small-scale geophysical anomalies in practically all geophysical fields, includ-ing, in the results obtained through seismic acquisition, gravimetric prospecting, magnetic survey, and electrical sounding and even through radiometric survey, thermal, and geochemical explorations. It is their vortex struc-ture that is the main cause behind uniting all types of geophysical fields in the local areas coinciding with the axial zone of such focal points [1].

The most highly broken-down rock areas also hap-pen to be the most “attractive” ones to serve in the capacity of escape paths for geodynamic energy and fluid currents. These same zones display high-visibility manifestations in all geophysical and geochemical fields generating mineral deposits of nearly all types. As a result of the migration of mobile components along the permeable zones, these object manifestations of recent geodynamic activity, which are often called disjunctive tectonic structures, manifest themselves not only in the physical but also in the geochemical fields, something that makes it possible to establish a basis for presorting the promising areas identified by the structural geo-physical methods.

The concept of geosoliton-like degassing provides both an explanation and a method for the gas chimneys used to separate vertical hydrocarbon migration areas [3] and to differentiate between conductive and non-conductive seismic faults. By definition [2, 3], the pres-ence or absence of gas chimneys, and their shape, length, and source of emergence, in their relationship to the hydrocarbon traps, all make it possible to break the lat-ter down into classes based on their respective produc-tivity and prospectivity. Proceeding from the geosoliton concept, what serves as a necessary pre-requirement for the development of gas chimneys is the nearby existence of an active geodynamical focal point and of its manifestation, namely, a breakdown zone (which is near-vertical, as a general rule). The breakdown degree of the rock cap in the focal point area will determine the degree of accumulation’s preservation, while the vertical evidence of the rock-breakdown focal point will deter-mine a probable oil-saturated layer. The presence of gas chimneys and VAMP-structures is seen in the specialist literature [2, 3] as an attribute of oil-and-gas bearing basins with an active fluid dynamic behavior, while the different types of gas seepage that are identified from seismic acquisition data make it possible to assess the processes of hydrocarbon accumulations formation and destruction and the productivity of the different hydro-carbon traps. All of this is in tune with the principles of the geosoliton concept of degassing of the Earth [1].

Over the past decade, features like gas chimneys and VAMP-structures, which indicate the processes of deep-earth degassing of the Earth and fluid migration, have been delineated in the Northern and Arctic regions of Western Siberia based on 3D seismic acquisition data in most fields across the entire length of seismic datasets. In the Cenomanian and Upper Cretaceous – Paleogene deposits, traces have been found of natural hydraulic fracturing of rock, with traces of mud volcano activities described in the northern part of the basin.

A prime example of that is the multilayer Van-Yegan field (up to 50 pay formations) in Western Siberia.

Fig. 1. Segment of a stacked seismic section with coherence attributes. !

Western Siberia, Van-Yegan oil-gas condensate field (50 pay formations). Depth of the oil-and-gas saturated layer reaches 1,900 meters, stretching from Cenomanian formations of Upper Cretaceous to the Tyumen suite of Middle Jurassic.

/'0. 1. 1-$2$&&3$ -+4-$43 0 +,-'*5,)2 6)7$-$&,&)0,'. 8+9+%&+( !

"'*'-:, 1+&-;7+&06)$ &$<,$7+4)6)&%$&0+,&)$ 2$0,)-)=%$&'$ (50 9-)%56,'#&3. 9>+0,)#). ?,+= &$<,$7+4)&)0&)0,' 1 900 2 – ), 0$&)2+&06'. 9>+0,)# #$-.&$7) 2$>+ %) ,@2$&06)A 0#',3 0-$%&$A @-3.

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!7-8 !"#$–%&'()* 2011"#$%&'(#

!"#$% & '()&%"#$)*

Sections of stacked seismic data with coherence attributes are shown on Fig. 1 and 2. The near-ver-tical fluid and gas migration path-ways are defined by focal points of high fracture porosity, decon-solidation, i.e. signs of rock forma-tion breakdown. The high degree of geodynamic activity caused by the processes of interior geosoliton-like degassing of the Earth had con-tributed to the formation there of a unique multipay oil-gas condensate field with a massive oil-and-gas sat-urated layer (1,900 meters) stretch-ing from Cenomanian formations to the Tyumen suite with reserve density in excess of 20 million tons per square kilometer. That multi-layered nature of numerous fields in Western Siberia is defined by the conditions that had governed their formation as a result of near-ver-tical hydrocarbon migrations and the filling of the fractured-porous hydrocarbon traps.

Based on the data obtained from seismic acquisition, gas-chemical prospecting, and ther-mal exploration, the attribution of the identified anomalies to one of unique fields is a proof of high prospectivity of such geological features from the view-points of discovering new oil and gas deposits and of developing and further improving methods used for their prospecting and delineation.

The high relevance of the processes of geodynamic activity and degassing of the Earth, and the role of fluid systems in the formation and transformation of the Earth’s crust and in the containment, therein, of solid, liquid, and gaseous mineral deposits, all of this finds its wide-spread application in present-day research and practical studies. Also, it places new demands on tech-niques used in the prediction and prospecting of new mineral deposits. The techniques used for surveying and prospecting such fields are based on the applica-tion of @D seismic acquisition and its integration with high-precision gravimetric determination, magnetic prospecting, gas surveying, and thermal prospecting methods.

Literature 1. R.M. Bembel, V.M. Megerya, S.R. Bembel, Geosolitons: The Earth’s Functional System and the Concepts for Prospecting and Developing Hydrocarbon Deposits, Vector Book Publishers, Tyumen, 2003; 344 pp. 2. Aminzadeh, F. and Connoly, d. Hydrocarbon Phase Detection and Ather Application of Chimney Technology, AAPG Int. Conference, Cancun, 2004.3. Heggland, R., Hydrocarbon Migration and Accumulation Above Salt Domes – Risking of Prospects by the Use of Gas Chimney, Proceedings of the 24th Annual GCSSEPM Foundation, Bob F. Perkins Research Conference, “Salt-Sediment Interaction and Hydrocarbon Prospectivity: Concepts, Application, and Case Studies for the 21st Century”, December 5-8, 2004, Houston, Texas. 2004.

,3*,3*+,%%#$# $'8"#")&"9+) -#"#8, %) 3,+,", :)33,/%) #-'3)%9 36,89 $"5&,+#$# +.6()%'&0).

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!"'%)86,7%#3*= +95+6,%-%9> )%#0)6'/ -# 0)*,"')6)0 3,/30#")&+,8(', $)&#->'0'2,3(#/ ' *,-6#+#/ 3I,0(' ( #8%#0. '& .%'()6=%9> 0,3*#"#78,%'/ -#8*+,"78),* +93#(.; -,"3-,(*'+%#3*= -#8#:%9> #:I,(*#+ 3 *#2(' &",%'5 #*("9*'5 &)6,7,/ %,4*' ' $)&), 4#"0'"#+)%'5 ' 3#+,"C,%3*+#+)%'5 *,>-%#6#$'/ '> -#'3() ' ()"*'"#+)%'5.

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

!"#$%&#'%&1. .)&/)"0 1.(., ()*)'+ !.(., .)&/)"0 ,.1. E)2<2"%327:: 9@768%27#"07#+ <%<3)&# B)&"%, 6278);8%+ '#=4)$6% % '#='#/236% &)<32'2I$)7%- @*")42$2'2$24. >?&)70, J=$. «!)632' .@6», 2003; 344 <. 2. Aminzadeh, F. and Connoly, d. Hydrocarbon Phase Detection and Ather Application of Chimney Technology. AAPG Int. Conference, Cancun, 2004.3. Heggland, R., Hydrocarbon Migration and Accumulation Above Salt Domes – Risking of Prospects by the Use of Gas Chimney, Proceedings of the 24th Annual GCSSEPM Foundation, Bob F. Perkins Research Conference, “Salt-Sediment Interaction and Hydrocarbon Prospectivity: Concepts, Application, and Case Studies for the 21st Century”, December 5-8, 2004, Houston, Texas. 2004.

Fig. 2. Segment of the coherence cube section !

in Van-Yegan field (based on 3D seismic acquisi-tion data).

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6)7$-$&,&)0,' &+ 1+&-;7+&06)2 2$0,)-)=%$&'' (9) 2+,$-'+>+2 0$A02)-+4#$%6' 3D).

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INTERVIEWINTERVIEWADVERTORIAL SECTION

Interview with Dmitry Sinukov, member of VZBT Board of Directors, the Head of Moscow Office

Oil and Gas Eurasia: Recently we informed the readers of our journal that VZBT won the tender for supply of drilling equipment for Surgutneftegaz. What is the current status of this order? How is it going?

Dmitry Sinukov: The order is big and complicated. Surgutneftegaz as a client has always put forward advanced and innovative requirements that demand a lot of techni-cal coordination. In compliance with the contract we would need to produce 24 oil rigs. The first sets are to be supplied in September, thereafter we are to deliver two sets of oil rigs monthly through the year.

OGE: Are any technical specifications reconsidered while processing the order?Sinukov: Yes, there are some changes in specifications. Surgutneftegaz special-

ists sometimes make some additions to specification list because they strive to get the equipment of the highest quality possible. We are also on our client’s side but we are restricted by a timeframe, by the prices defined by tender. We have to act accord-ingly and are forced to search for compromises like we normally do with other clients. Another problem we face is receiving imported components on time. We order General Electric engines directly from the US and have to speed up the delivery. Some compo-nents specified by Surgutneftegaz are manufactured by Chinese producers and it often raises both technical and logistical issues. In general, our drilling rig of the sixth genera-

Flexible StrategyVZBT Offers Equipment Leasing to the Customers

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Page 61: Oil&Gas Eurasia July-August 2011

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tion is so unique that we are able to integrate any imported components with it. Also a lot of check assembly work is to be done in the future. Our customer doesn’t want to loose time in the field and asks us to assemble everything in factory testing area and launch several rigs. Then we are going to provide services for assembling kits in Surgut, pro-viding commissioning and start-up while drilling the first well. By the way, our custom-er inspects technological process during the full period of product manufacturing. The customer also inspects technological process of spare parts and components we order from other companies.

OGE: It wasn’t an easy order for you financially, was it? Sinukov: It wasn’t and it’s still is not easy. Even now it’s hard to say, what the final

result will be. From the moment we signed the contract in December 2010 the price of the metal rose twice this year already. There is still a rising tendency, no one eliminat-ed inflation. The fact that we had to involve significant credit resources testifies that it’s a tuff contract. We had to buy metal and components, though we had a poor prepay-ment. So we had to take a reasonably heavy principal in order to launch tenders and credit interest is lowering already a low-level viability. Nevertheless, we are doing our best to get good results.

OGE: Most of the plant’s facilities must be working for this order. What is the situa-tion with other contracts?

Sinukov: The plant’s capacity allows us to increase the production volume signifi-cantly. We fulfil other orders on time. Recently we supplied two drilling kits for the Perm branch of the Eurasia drilling company under the modernization program for that com-pany. We supply preventer equipment, spare parts and knots, and take part in other ten-ders for drilling kits supply.

Apart from that I would like to mention that today VZBT offers its potential buyers to lease equipment. It’s especially vital for companies that do not have enough resourc-es to pay us when signing the contract. We have an opportunity to help them by pulling in a financial partner that is Sberbank leasing company. By the way, in the long run it is much more profitable for a buyer because there is no property tax and payments upon lease can be attributed directly to prime costs. This is an important issue when we talk about big orders.

OGE: How successful is VZBT in preventer equipment production?Sinukov: For decades VZBT has been the biggest supplier of preventer equipment

in the country. Nowadays a number of companies compete with us at this market seg-ment. On the other hand, the group of technical experts of VZBT won the government prize for the development of this kind of equipment, although there were many compa-nies participating including some of Gazprom structures among them. The orders are usually off-standard and we produce kits and special packages of the preventer equip-ment. Thus we developed the line-up of the bore caliber from 180 mm to 1350 mm, and we are not going to stop. We work hard, particularly on improvement of corrosive resis-tance. Another problem that often comes up is counterfeit goods. Price is crucial when purchasing such equipment but we run reliable testing system that can not be cheap. We even show faulted bodies of preventers to clients when they visit our factory. When the body bursts it is obvious that the existing technological system prevents us from manu-facturing low-quality products. Most producers can’t show anything like this.

OGE: Maybe it was worth setting up an Association of Drilling Equipment Manufacturers?

Sinukov: Any association is established with an ultimate goal to protect interests of an industry sector. In this respect you need to have civil instruments for lobbying, which in our country are replaced with the phenomenon known as “corruption”. We would be willing to lobby deputies and even political parties had they been capable to influence the situation. But today deputies do not take decisions, so international instruments for lob-bying do not work for us.

OGE: There is a general opinion that production in Russia is less profitable than in China primarily because of energy costs. In Russia we have to heat premises during cold seasons. Besides, energy costs and other head costs including labor costs increase the final price of any production.

Sinukov: They tend to have earthquakes instead. In addition to this factor of risk I would argue with the fact that their workforce is so cheap. Urbanization process is going

Page 62: Oil&Gas Eurasia July-August 2011

6060 Oil&GasEURASIA

INTERVIEW INTERVIEW ADVERTORIAL SECTION

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fast and migration from rural areas to big cities results in raising life costs and increase in prices of natural resources. China mainly exports resourc-es so relatively low labor costs are to be balanced by electricity and gas pric-es and so on. We are suc-cessfully winning ten-ders against the Chinese and our last contract with Surgutneftegaz just proves that. We have won the tender not because some sort of administra-tive instruction to work with the Russian compa-nies came from author-ities (may be we would not mind, but that was not the case) but because we were able to come up with a better price.

I may repeat it, but unlike the Chinese, we cre-ate jobs inside Russia, pay taxes here and deserve to have some preferenc-es at domestic market. The state must realize that it is necessary to protect the domestic market. This will secure the technolog-ical stability of the state alongside with social sta-bility. Take, for example, President Sarkozi who was battling to get the contract for production of Mistral helicopter carriers. He says that the contract will pro-vide jobs for more than a thousand workers at French shipyards. We do not even dream about such support from the state, although we have much more employ-ees working for us. As for Chinese manufacturers, they get lots of different “gifts” from the state, such as non-interest preferences, etc., especially when they produce goods for export.

As for your question regarding heating problem, I can tell that there are sever-al ways to resolve the issue. It’s possible to go for modern energy saving technol-ogies, to go for audit of the enterprise and get some guidelines and recommenda-tions, to introduce economizing programme and reach energy efficiency, but all of that demands additional resources. For us it’s hardly the case because we had to get a loan in order to fulfil our contract. Unfortunately, the initiative to raise export duties on for-eign drilling equipment export suggested by Vladimir Putin at the last Economic Forum has not been implemented yet. Though Russian producers of oil and gas equipment would benefit significantly if Chinese exporters had to pay 30-40 percent duty for their imported products when entering our market. Those who prefer using imported equip-ment should pay more and add up money to the state budget. To take cars, for exam-ple. There is an import duty, and owners of foreign-made cars have to pay it.

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D4"+5'&$( F","&0A"3 9';,"0 -)50 ("7.)&'4A&)7) %-('34*12"7) -) 50('-&', >?@ 3 7)4)3&), )8.5" +),-'&.. 3 J54). N),,"&0.(%* )(7'&.9'<.)&&=" .9,"&"&.*, )& 5+'9'4: «!= ):"&A ('$=, :0) + &'G"; 5-4):"&&); ,"#$%&'()$-&); +),'&$" -(.5)"$.&.45* E+5-"(0 3=5):';G"7) +4'55'. S0), &"5),&"&&), "2" /)4AG" %+("-.0 -)9.<.. PGS 3 B)55.. . 9' "" -("$"4',.. T ):"&A 3=5)-+) <"&1 -()8"55.)&'4A&=" . :"4)3":"5+." +':"503' C(.* . %3"("&, :0) 3 53)"; &)3); $)4#&)50. )& 3&"5"0 /)4AG); 3+4'$ 3 -)3=G"&." E88"+0.3&)-50. 7")4)7.:"5+); ('93"$+. ()55.;5+)7) G"4A8', ) &")/6)$.,)50. +)0)(); 0'+ ,&)7) 7)3)(*0».

The International Petroleum Geo-Services Company (PGS), which conducts marine geo-

physical studies, will soon strength-en its presence in the CIS. As of August 1, the position of the Head of the PGS Group Representation Office in Russia will be taken by Yuri Ampilov, replacing Alexander Dementyev.

Yuri Ampilov is well known in the oil and gas industry of Russia for his previous years of work at the Research Institute of Marine Geophysics VMNPO SOYUZMORGEO and Gazprom VNIIGAZ LLC (GAZPROM’s lead research centre). Prior to joining the PGS, he served as director of the Offshore Oil and Gas Centre at VNIIGAZ. From May to December 2003, Yuri Ampilov served as the chairman of the State Commission on Mineral Resources (MNR SRC).

The new head of PGS in Russia graduated from the Department of Geophysics, Geological Faculty of Moscow State University in 1978. In 1994, he defended his doctoral thesis and received his doctorate in Physics and Mathematics, and in 2000 – the title of professor. Yuri Ampilov has authored more than 170 published scientific works, including eight monographs and six textbooks and teaching aids. More than 30 works were published abroad. On July 30, 2010, Yuri Ampilov was awarded the honorary title of The Honored Scientist of Russian Federation by Presidential Decree No. 950.

Alexander Dementiev will take over as Regional Manager for the CIS coun-tries at the head office in Oslo. Commenting on this organizational reassign-ment, he said: “We are very pleased that a professional of the highest class has joined our close-knit international team. Beyond doubt, this will further strengthen PGS’ position in Russia and abroad. I truly appreciate Yuri’s profes-sional and human qualities and I am sure that in his new role, he will make a significant contribution to improving the geological exploration of the Russian shelf, a need about which there has been so much talk in recent years.”

PGS Strengthens Team in Russia PGS !"#$%&'$( ")*+,-! . /)0011

Page 64: Oil&Gas Eurasia July-August 2011

6262 Oil&GasEURASIA

Sibneftegeofizika: Make Oil Exploration Easier!"#$ " %&' ()#( * +,-*&)%.

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SEISMIC SURVEYSEISMIC SURVEYADVERTORIAL SECTION

Sibneftegeofizika Company celebrates 40th anniversary. Sibneftegeofizika general director Stanislav Losev tells a story of company success.

Stanislav Yuryevich, tell us please about the main lines of your compa-ny’s activities.

Stanislav Losev: Sibneftegeofizika was founded on 3 September 1971 as a subdivision within the USSR Oil Ministry. The company’s current organiza-tional and legal form is an open joint-stock society. The company was estab-lished to pursue scientific and production-oriented goals in the field of seis-mic survey. However, the logic of subsequent events had taken a course that made it imperative for the company to shift its activities completely toward the production-oriented operations. We have seen several generations of experts come and go since those early days. Still, the original elements of our former scientific orientation have remained both in our approach to what we do and in our selection of the personnel to do it. The greater part of Sibneftegeofizika’s computer software and development products cur-rently applied in our work are the result of many years of our earlier research activities.

Today, Sibneftegeofizika performs a full range of seismic survey operations, including field acquisitions in 2D and 3D modifications, seismic data processing and all-inclusive interpreta-tion of geological and geophysical data prior to their conversion into three-dimensional geo-logical models. Enlisting the services of a specialist unit with the Siberian Experimental and Methodological Geophysical Drill-hole Survey Company (SOMGEIS), we perform drill-hole geo-physical investigations and VSP seismic profiling. Field seismic exploration work is the compa-ny’s main field of activity earning it close to 90 percent of its income.

What up-to-date equipment and facilities do you have?Losev: To perform seismic exploration work in the field, the company operates 11 seis-

mic prospecting crews equipped with state-of-the-art equipment, including 20 recording sys-tems (mostly latest Sercel 408/428 models), over a hundred different drilling rigs, some thir-ty vibration units, and 40 Yenisei-type electromagnetic impulse-generating seismic vibrators. Topographic survey crews are equipped with advanced global-positioning navigational sys-tems. The geophysical teams with our field units are equipped with state-of-the-art computers and software support programs which are for the most part developed by Sibneftegeofizika’s own experts and built into our integrated system of fieldwork planning, control and supervision. Over the last decade, our organization has recorded more than 70,000 linear kilometers of 2D seismic profiles and performed over 9,000 square kilometers of 3D seismic surveys.

What is characteristic of Sibneftegeofizika’s work in the field of processing and interpreta-tion of seismic data is:

The use of software tools developed by world market leaders; !

Development of custom-tailored solutions for each site being explored; and !

A high degree of individual skills of our experts. !

For the processing of seismic material, our company possesses unique methodologies and techniques for the solution of tasks concerning such areas as near-surface effects compensa-tion; the migration mapping of seismographic records; suppression of all sorts of interferences; and analysis of field seismic acquisition data. The final outcome of all-inclusive interpretation of seismic acquisition data is the construction of a digital three-dimensional geological model of the geological body surveyed, with that outcome being presented in the form of lithological sec-tions (cubes), porosity stratification factors, permeability coefficients or hydrocarbon saturation factors. To perform those tasks, it is necessary to solve the traditional problems of seismic sur-vey, viz. to determine the occurrence depth of the reflecting horizons being the survey targets, perform a quantitative interpretation of the geographic information system’s results, and per-form an inverse modeling of seismic data in order to make a prediction of the desired quantities. Our company has a perfect command of all of the above techniques and methods.

This article was supplied courtesy of Sibneftegeofizika !"#"+7 0*,81&"#(',$# >?> «!%4$,@",A,1@%:%.#»

Page 65: Oil&Gas Eurasia July-August 2011

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What is the geography of the company’s activities today? Who are the company’s customers?Losev: The geography of the Sibneftegeofizika activities today is fairly broad, stretching as it

does from the north-end of Yamal Peninsula in the north to the southern regions of Uzbekistan in the south and from Mangyshlak Peninsula in the west to Yakutia in the east. Seismic work has been performed in Mongolia, Kazakhstan and Uzbekistan. The various regions of Eastern and Western Siberia constitute the main areas where the company is conducting its operations today. Currently, we have contracts signed to perform seismic survey work in Yamal-Nenets District, Khanty-Mansiysk District, Tomsk Region, and Yakutia.

Among our principal customers are the following oil and gas companies: Tomskneft VNK, Gazprom Dobycha Noyabrsk, Gazpromneft Shelf, Gazpromneft NNG, Novatek, Sibneftegaz, Surgutneftegaz, Kumskaya Neft, Matyushkinskaya Vertikal, Slavneft-Megionneftegaz, Tomskgazprom, Gazpromneft Vostok, Slavneft-Krasnoyarskneftegaz, STS-Servis, Petrogrand, Kolvaneft, Novosibirskneftegaz, Terneftegaz, Rosneft-Kazahstan, Tuimaada Neft, TNK Uvat, Samotlorneftegaz, TNK-Nizhnevartovsk, Vostokgazprom and others.

Also, Sibneftegeofizika has performed government contracts for the conduct of region-al geophysical operations. We have already performed work under contracts with the Subsoil Use Department for Khanty-Mansiysk District, the Subsoil Use Department for Yamal-Nenets District and the Subsoil Use Department for Siberian Federal District. In the forthcoming sur-veying season we shall perform work under a contract with the Subsoil Use Department for the Republic of Sakha (Yakutia).

How would you describe your company’s special characteristics and particular style?Losev: The company’s own style consists in the high-quality performance of work at all stag-

es of the operation, viz. field acquisition and data processing and interpretation. In the conduct of acquisition work in the field, it is in the following way that we do it in our organization to obtain high-quality initial data:

The use of the latest in data acquisition equipment; Custom-tailored and high-level analytical approaches to the selection of conditions gov- !

erning data acquisition and seismic response stimulation;The conduct of test surveys during the whole of the surveying season; !

The use of our own software tools, methods and techniques; and !

The use of special methods of production engineering. !

To raise the level of objectivity of operational control surveillance of the seismic material quality, Sibneftegeofizika has instituted its own service of internal controls performed by geo-physicists seconded to the seismic prospecting crews operating in the field during the acqui-sition period. The prime objective of the geophysicist attached to a field prospecting crew is to perform quality monitoring of the acquired material and take steps to assure improve-ments in that quality. Significantly, the geophysicist concerned does not report to the man-agement of the crew. It is this kind of organizational set-up that has helped promote our high quality of seismic data acquisition. Strict adherence to that particular course has, on occa-sions, led to the extension of operational time-limits or failure to meet the deadlines estab-lished for the execution of an order as a whole. Nevertheless, the prevailing feeling in our company is that on-time performance of a work scope, to the detriment of its quality, is sim-ply not acceptable.

How do you view your company’s prospects?Losev: Trivial as it may sound, our company is pinning its hopes on the expected rise in oil

prices. The higher the price index the more money is invested by oil and gas companies into new programs to further specify the geological structure of mineral deposit fields and to search for and explore the newer ones and, consequently, the greater the demand for our own servic-es. The 2008 financial crisis has dropped, by a third, our work scopes, financial well-being and profits. The oil prices have now risen to their pre-crisis levels. Yet, no visible stirring of the oil and gas companies’ activities is anywhere to be seen, however, even though there are some observed signs of a certain revival of the market. Companies are not eager right now to seek out new license areas, something that can be seen from numerous subsoil-use tenders that have failed merely because of the absence of bidders. As a consequence of that, only a small num-ber of orders are placed for seismic survey work. This, however, is only a result of certain iner-tia and of planning approaches that are based solely on the earlier volumes. My own prediction is that, if not the forthcoming field season, then the next one after that to be rich in profitable orders and deals. What makes that optimistic forecast possible is the Russian Government’s declared intention to double the size of budget appropriations allocated to geological explora-tion activities.

On Sibneftegeofizika 40th anniversary, it is with considerable optimism and confidence that we are looking into the future

Page 66: Oil&Gas Eurasia July-August 2011

6464 Oil&GasEURASIA

Searching for New Horizons!"#$% &%'(&%)*+#$

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INNOVATIONSINNOVATIONSADVERTORIAL SECTION

Building on over 175 years of manufacturing high quality, reliable and innovative products, Sulzer pumps searches for new horizons in Russia.

For many years Sulzer Pumps developed an aggressive expansion program and has a truly global footprint of 14 manufacturing facilities and over 65 service centers around the world. The map below provides an overview

In 2010 we started a new development program for our activities in Russia, establish-ing a new Sulzer legal entity (LE) in Moscow in addition to our existing LE in St Petersburg. Meanwhile, we searched for a suitable location for our first service center to provide quali-ty repairs, retrofits, spare parts, field services and training to all our customers in the indus-trial area around Moscow.

After visiting several possible locations we identified a building at Khimki (Moscow Region) and after only seven months the facility was totally refurbished. New walls, roof, floor and the necessary equipment for a modern service center with overhead cranes, com-pressed air supply, electricity, heating, etc. The layout meets Sulzer Lean manufacturing principles with all equipment being state-of-the-art, brand new machines. This allows our facility to manufacture parts for Sulzer and third party pumps in accordance to our high quality standards.

During this period we also recruited, trained and devel-oped the Sulzer Moscow ser-vice center personnel includ-ing management, engineering, logistics, project management and shop floor specialists. After selection from highly quali-fied Russian professionals, we mobilized our colleagues in Europe for training in Germany, Great Britain and other loca-tions where they could be fully

Itamar Vandelli!"#$#% &#'()**+

Branch headquarter L.%,-2/%8.'8% $"68%<6+-+&'(Manufacturing facilities D8"'</"61./+&&0+ $8+6$8'(.'(

Service centers @+8/'1-7+&.80Sales officesEJ'10 $8"6%*

Page 67: Oil&Gas Eurasia July-August 2011

6565!"#$% & '()!"#$%&'

&(()"$*&&&(()"$*&&!"#$%& !%'&"()*+ ,-"-%.

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D-%&0 $" 8%1C'8+&'3 6+(.+-=&"1.' Sulzer Pumps &+ ";8%&'5'/%3.1( :"12"/12"> ",-%1.=3. O+-= 2"#$%&'' – 6" 2"&7% 2011 ;"6% ".280.= +4+ "6'& 1+8/'1&0> 7+&.8, ' %2.'/&%( 8%,".% / F."# &%$8%/-+&'' )*+ /+6+.1(. H%2*+ /+6+.1( $"'12 $-"4%6"2 6-( 7+&.8"/ ",1-)*'/%&'( ' 1+8/'1&0? 7+&.8"/, ' 2"#$+.+&.&0? 1$+7'%-'1."/-'&*+&+8"/, $8"C+6C'? ",)5+&'+ / 2"#$%&'' Sulzer, 6-( 8%,".0 / F.'? 7+&.8%?.

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B "1&"/+ 6+(.+-=&"1.' @-)*,0 2-'+&.12"> $"66+8*2' 2"#$%&'' Sulzer <%-"*+& $8'&7'$ «$8"J+11'"&%-'<# $+81"&%-% – <%-"; FJJ+2.'/&"> 8%,".0». B $+8/"# 1+8/'1&"# 7+&.8+ 8+%-'<)+.1( $8";8%##% F2"&"#'5&";" $8"'</"61./% 2"#$%&'', ",+1$+5'/%34%( 1.%&6%8.'<%7'3 $8"7+6)8, .+?&"-";'5+12)3 8%<8%,".2) ' 1"/+8C+&1./"/%&'+ $8"'</"61./+&&0? $8"7+11"/. I-%;"6%8( 8%<&"1."8"&&+> $"6;"."/2+ 1$+7'%-'1."/ 2"#$%&'', '<;"."/-+&&0+ / 9"11'' 6+.%-' ' )1-);', $8+6"1.%/-(+#0+ Sulzer, ",+1$+5%. ++ 2-'+&.%# /01"2'+ F21$-)%.%7'"&&0+ ?%8%2.+8'1.'2', 6-'.+-=&0> 18"2 1-)*,0 ' &+",?"6'#0+ ;%8%&.'' &%6+*&"1.' ","8)6"/%&'(.

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trained in Sulzer standards and procedures for manu-facturing and field service. In the engineering departments Sulzer transferred to its new Russian colleagues the nec-essary pumping knowledge for the design of centrifugal pumps. This included mate-rial technology, new hydrau-lics efficiency improvement, test bed procedures, quali-ty control norms, machin-ing, assembly, etc. All these measures allow our team to professionally address all the centrifugal pumping system problems that our customers may face. We focus on inno-vative, technical solutions to increase efficiency, deliver energy savings, double or triple the mean time between failures, analysis of customers pumps to suggest and implement improvements that increase reliability and operating life with the associated reduction in maintenance costs.

The main capabilities of Khimki service center are:Repair and refurbishment of both Sulzer and third party pumps. !

Retrofits of all kind of rotating equipment, upgrading material technologies and !

operational parameters as per customers needs.Modern spare parts manufacturing center enabling us to quickly supply parts for !

many kinds of rotating equipment.24/7 hot line to field service engineering assures a fast response to customers !

needs.Support for maintenance contracts inside customers plants. !

Support for spare parts supply contracts including administration of stock invento- !

ry assuring fast delivery and minimizing downtime of your equipment.On site engineering analysis of pump systems to identify the optimum !

technical and pay back system improvements.

Our development plans are not limited to the Moscow Region. Our target for 2011 is to identify and implement another service center before the end of the year, this work is already well underway. We are also seeking further potential locations for service islands and centers plus, of course, Sulzer-trained compe-tent and professional engineers to operate these new facilities.

In addition to these various service locations provision of a new pump assembly plant is also being considered.

The core of Sulzer Customer Support Services (CSS) operating principle is Performance Through People. Our Lean manufacturing program is being imple-mented in the first service center to ensure standardization of procedures, engi-neering and rationalization of processes. Extensive training assures the parts made in and services provided by Sulzer in Russia will provide our customers the high performance, durability and dependability they need.

Supporting all these activities are the Sulzer Core Values that are also being introduced into Russia, ensuring all our locations are world class pump solu-tions providers.

Thus our Core Values are:Customer Partnership - we exceed the expectations of our customers !

with innovative and competitive solutionsOperational Excellence - we perform on the basis of structured work !

processes and LEAN principles.Committed People -we are committed to high standards and show !

respect for people.

" ", . -/ZAO Sulzer Pumps,

St Petersburg

/ / / Sulzer Manufacturing / Packaging / test Centre

" "( ), . / Sulzer

Pumps Rus LLC (New LE), Moscow

/ /Service Centre West Siberia / East Siberia region

- , . /Service Centre, Khimki

( , )/ Service Islands / Stations,

(Regions TBC examples only shown above)

. / Service Station, Yekaterinburg

. / Service Centre

Oktiabrisky, Ufa

Next SC will be in UFA region, complete within 2011

!"#$%&'() !* +%$#, - ./)0# 123, 45406/0(#./+4, 7/8"/0(.4-/04 0/ 2011 94$:

Page 68: Oil&Gas Eurasia July-August 2011

6666 Oil&GasEURASIA

Cables That Perform Better!"#"$%, &"'($")*+, -./0,

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G(#$,80%5&6( 3+&+$6 # 3"'<,&,0"/+&&6' #(05(=&,3"' 8" HI-049; !

J"#@',80%5&6( 3+&+$6 8" HI-072; !

J"#@',80%5&6( 3+&+$6 # 8:+#$,=(#3, "<4+$6', 80%5%', 8" HI-051. !

G(#$,80%5&6( 3+&+$6 8" HI-049 "<:+5+)$ .(:6' 0%5"' 80(,'-*(#$/ 8" #0+/&(&,) #" #$+&5+0$&6', 3+&+$+', 8" KLDH 16853 # '($+::,=(#3,' #(05(=&,3"'. M:+7"5+0%

EQUIPMENTEQUIPMENTADVERTORIAL SECTION

With its ups and downs, the global economy is making increasingly high demands of manufacturers in terms of efficiency and production safety from year to year. For oil and gas companies, this topic is particularly relevant since

the safe and uninterrupted operation of equipment is a prerequisite for efficient produc-tion. The search of advanced technologies, equipment and accessories that enhance the safety of production and simultaneously help reduce operating costs is among pri-ority for mining companies. While fulfilling this need on behalf of the customers, the Severstal-metiz Company created a unique design of steel cables for fixed drilling rigs for oil and gas wells and deep drilling equipment.

Wire cables are the flexible link between the heavy drilling tool and a winch. This part of the rig’s sheave system bears a significant load (lifting and suspending the heavy drill-ing equipment weight). Therefore, the cables for the rigs should feature high mechanical strength (to withstand multiple loads like stretching, bending, vibration, contact stress, the outer and inner wear of wires), being at the same time flexible enough. This class of products includes the designs developed by the Severstal-metiz engineers:

6-strand cables with combined core as per TU-049; !

8-strand cables as per TU-072; !

8-strand cables with plastic compacted strands as per TU-051. !

The six-strand cables as per TU-049 have a number of advantages over the standard cables as per GOST 16853 with a metal core. Thanks to the special design of the outer strands, the new cables are characterized by higher resistance to abrasion, but they are more flexible due to design features of the product core. The presence of organic fill-ers does not only reduce the influence of dynamic loads on the cable, but also provides

Note: here and below the diagrams are provided for the visual comparison of new cables designs’ properties relative to the cable properties as per GOST 16853. The highlighted area reflects the properties of the new TU; the area outlined by the solid black line are the cable properties according to GOST.!0,'(=+&,(: ;5(#@ , 5+:(( 5,+70+''6 80,/"5%$#% 5:% &+7:%5&"7" #0+/&(&,% #/"1#$/ &"/6A 3"&#$0-3.,1 3+&+$"/ "$&"#,$(:@&" #/"1#$/ 3+&+$+ 8" KLDH 16853. L<:+#$@, /65(:(&&+% ./($"' – #/"1#$/+ &"/"7" HI, "<:+#$@, "=(0=(&&+% #8:"B&"1 =(0&"1 :,&,(1 – #/"1#$/+ 3+&+$+ 8" KLDH.

TU-049 Type 1 !

!"-049 #$% 1 !

TU-049 Type 2 !

!"-049 #$% 2 !

This article was supplied courtesy of Severstal-metiz Company !"#"$% &'()*+"#,-(.# /*0&#.1(2 «!(,('+"#-$-0("13»

Page 69: Oil&Gas Eurasia July-August 2011

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an additional source of lubrication inside the product. Today, Severstal-metiz offers consumers two versions of these cables, namely the round-strand cable (TU-049, Type 1) and the cables with plastic com-pacted strands (TU-049, Type 2). Type 2 cables offer additional benefits with respect to the round-strand counterpart due to the higher structural density of inner wire; they are loaded more evenly, which reduc-es the sporadical breaks of wires within the strands to a minimum. The tensile strength of such products is 15-20 percent higher than the similar cables in accordance with the GOST for the same diameter. Thanks to compact design, the cables feature higher resistance to transverse crushing, whereas by reducing the contact stress, we increase the wear resistance of wires and strands. In addition, less wear and tear of pulleys and drums is ensured through larger area of contact with the bearing surface of the cable. The TU-049-based cables are rec-ommended for use on the drums without grooves or with parallel grooves.

The main benefits of 8-strand cable according to TU-072, compared to the GOST 16853-based cables with organic core, include increased flexibility, higher fatigue resistance, greater tensile strength and lon-ger service life. It should be noted that these cables are recommended for use in small sheaves and drums, where the ratio of the drum diameter to the cable diameter is less than 20. The products are designed for drums with the Lebus-grooved drums.

!"-072 !

TU-072 !

Page 70: Oil&Gas Eurasia July-August 2011

6868 Oil&GasEURASIA

EQUIPMENT EQUIPMENT ADVERTORIAL SECTION

J"#@',80%5&6( 3+&+$6 8" HI-051 # 8:+#$,=(#3, "<4+$6-', 80%5%',, 3+3 , 3+&+$6 8" HI-072, $+34( "<:+5+)$ 8"/6-B(&&"1 7,<3"#$@), /6#"3,' #"80"$,/:(&,(' -#$+:"#$,, <ó:@B(1 0+;06/&"1 80"=&"#$@) 8" #0+/&(&,) #" #$+&5+0$-&6', 3+&+$+', 8" KLDH , 80(5&+;&+=(&6 5:% <+0+<+&"/ # &+0(;3"1 $,8+ «P(<-#». C;5(:,% 0(3"'(&5"/+&6 5:% "#&+#$-3, <-0"/6A -#$+&"/"3, #""$&"B(&,( 5,+'($0+ <+0+<+&+ , 5,+'($0+ 3+&+$+ &+ 3"$"06A #"#$+/:%($ 20-24.

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R+ 8"#:(5&,( 8%$@ :($ 3"'8+&,% 5"<,:+#@ ;&+=,$(:@&"7" 80"70(##+ / $(A&":"7,=(-#3"' 8:+&(. !"%/,:+#@ .(:+% :,&(13+ -&,3+:@&6A #8(.,+:,;,0"/+&&6A 80"5-3$"/ , -#:-7. !0, 2$"', «D(/(0#$+:@-'($,;» &( "#$+&+/:,/+($#% &+ 5"#$,7&-$"' , $*+$(:@&" ,;-=+($ 80"<:('6 , 8"$0(<&"#$, ;+3+;=,3"/, =$"<6 80(5"#$+/:%$@ "8$,'+:@&6( $(A-&,=(#3,( 0(B(&,%, #<+:+&#,0"/+&&6( 8" .(&( , 3+=(#$/- , 80,&"#%*,( '+3#,'+:@&-) 8":@;- 8"$0(<,$(:).

The eight-strand cables based on TU-051 with the plastic compacted strands, just like TU-072-compliant cables, also offer increased flexibility and high fatigue resistance, higher tensile strength as compared to the standard GOST cables designed for the Lebus-grooved drums. The products are recommended for the rigs, which drum-to-cable diameter ratio is 20-24. The advantages of the cables offered by Severstal-metiz over the standard hardware are obvious, but to ensure the maximum effect it would not be enough to buy a good product, it is necessary to make the right selection and rig it up. To provide consumers with full tech-nical support, the company has established the cable service center, where experts help customers in choosing the optimal design, participate in the rigging, conduct the train-ing sessions, monitor the service life length of the cables, and develop more custom-tailored products. In light of the wide variety of mining equipment and specific operating conditions, to seek guidance from the cable service center is a must in the selection of your cables.

While actively expanding its service line of business, Severstal-metiz has been master-ing a technology for pre-stretching of the cables. This routine allows you to remove the residual structural stress and get rid of operational elongation. The torque of such cables is much lower than the torque of a similar product of the same design. In addition, the cable pre-stretching allows the customer to abandon the initial run-in of the cable and thereby save money.

The company has made a great leap forward in technological terms over the past five years. A whole line of unique specialty products has been launched. Carefully study-ing the concerns and needs of the customers, the company strives to provide the opti-mum technical solution, a balance of price and quality, and bring the maximum bene-fit to the consumer.

!"-051 #$% 2 !

!U-051 Type 2 !

Contact Us:Area Sales Office in Russia and CIS:

Vyacheslav ShirayevskyPhone: +7 (8202) 53-91-67

Fax: + (8202) 53-85-20e-mail: [email protected]

Elena TsibulinaPhone: +7 (8442) 63-40-98, 62-42-00

Fax: +7 (8442) 63-42-43e-mail: [email protected]

Export Sales Office:Natalya Avanova

Phone/fax: +7 (495) 926-77-66, ext.6545e-mail: [email protected]

Technical Support:Morris Baldwin

Phone: +7 (8202) 53-93-79Fax: +7 (8202) 53-86-10

e-mail: [email protected]

Dmitry SokolovPhone: +7 (8202) 53-89-58

Fax: +7 (8202) 53-86-10e-mail: [email protected]

www.severstalmetiz.com

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Page 71: Oil&Gas Eurasia July-August 2011

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High above the deep valleys and canyons in Colorado’s Piceance Basin, Frank Westcott, the president of Colorado-based Native Navigation faces a challenge.

He is listening to his directional driller’s plan to navigate a new bore hole through 16 other wells already spudded from the drill pad they are standing on. “The risk in this play is not drilling a dry hole. Suddenly, drilling a hole has become even more techni-cal,” says Westcott.

Directional drilling of multiple holes from a single drill pad is a standard practice in the Piceance Basin’s prolific oil and gas fields, but the risks are enormous as the holes are in close proximity and a well collision is a possibility.

Robert Simpson !"#$%& '()*+",

Precision matters when spending millions of dollars drilling for minerals or oil and gas in harsh environments such as the North Sea, the frozen Arctic or scorching deserts of North Africa. That’s why more and more drilling companies are relying on gyroscopic surveying tools for accuracy.

!"# $%"&'## ( )*+& +*$,-# .*/&0',) #12*.3&4,), '&56# #/# 7303 ( 1%"*(,) 2/#436#-&12#) %1/*(#8), '3."#4&", ( 9&(&"'*4 4*"&, .*2",6*: /;+*4 <"26#2& #/# *$*==&'',) 1*/'>&4 .%16,'8) 9&(&"'*: <5"#2#, 7+& 6"368618 4#//#*', +*//3"*(, 16&.&'; 6*-'*16# #4&&6 *7"*4'*& 0'3-&'#&. ?4&''* .*@6*4% (1& $*/;A& # $*/;A& $%"*(,) 2*4.3'#: #1.*/;0%B6 ( 1(*&: "3$*6& 7#"*12*.#-&12#& #'2/#'*4&6", +/8 .*/%-&'#8 4321#43/;'* 6*-',) #04&"&'#:.

ACCURACY / !"#$"%!& The North-seeking GyroTracer delivers highly accurate, non-magnetic devi- !

ations in magnetically disturbed environments, such as inside casings, a drill pipe

or magnetic rock.

The gyroscope is low-power and lightweight, with the capacity of operating !

in a wireline or battery-operated mode.

The tool delivers azimuth and inclination measurements accurate from 0-70 !

degrees from vertical.

J-+$#%$8-=*#%-, -&%/-&$.*4+ GyroTracer™ – 74$ 8+-)$+ # (-&'.-=*#%- !

&'#4+'-1'*.". A-+$#%$8$. (KFJ). 2+-)$+ &* 8$(1*+:*& 1/-@&-< .'A&-4&"B

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Page 72: Oil&Gas Eurasia July-August 2011

7070 Oil&GasEURASIA

GYROSCOPES GYROSCOPES ADVERTORIAL SECTION

212,06. 2$#/* 8*+1$&'='/0&$A$ 9'.*+' #%1':-&; ;A/;)-/- - (1' .*#@?' #8;#4@ %$.8'-&-< 8+-A/'#-/- *C* +'9 8+$.*+-40 #%1':-&;. «H" $8;#4-/- 8+-)$+ ($ 4$=%- 8+-1@9%- (9'1*+3'<C*, 4$=%- 8+*("(;C*A$ $)#/*($1'&-@) - &'='/- +')$4" # A/;)-&" 1 300 .. 5$A(' ." -91/*%/- 8+-)$+ - 8$/;=-/- ('&&"*, 4$ $)&'+;:-/-, =4$ $4%/$&*&-* 1 4$=%* 8+-1@9%- #$#4'1-/$ 7,28 A+'(;#$1, ' '9-.;4 – 212,16. H" &* .$A/- 8$1*+-40 4'%$, &*1*-+$@4&$, 1$#8+$-91$(-.$#4-!» – A$1$+-4 D*.'(*&-.

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Directional drilling is a high stakes spe-cialty – a successful hole in the Piceance Basin can average 1.2 to 1.4 billion cubic feet of natural gas while a mistake in accuracy could cost millions of dollars and irreparably damage the company’s reputation.

New downhole gyroscopic survey navi-gation systems are making the job a lot eas-ier for directional drillers, and the compa-ny on the forefront of survey technology is Stockholm Precision Tools AB (SPT AB). SPT AB has been in the business of devel-oping survey technology since 1990, but the main product of the company is the North-seeking GyroTracer™, a survey tool many in the industry have hailed as the most reliable and accurate available globally.

“When you have as many as 22 wells spudded from a single drill pad, you need a reliable tool for accuracy and one not affect-ed by magnetic interference. As soon as we started using the North-seeking GyroTracer, we noticed the difference,” says Westcott. “The GyroTracer has worked perfectly, 100 percent of the time.”

Westcott is not alone in his assessment of the North-seeking GyroTracer. “The technol-ogy is heads above the rest,” agrees Justin Semadeni, Technical Services Manager for Major Drilling America, Inc.

Major Drilling technicians surveyed an NQ core hole with the SPT gyro in memo-ry mode to a measured depth of 1,300 meters – inclination was 7.38 degrees and azi-muth was 212.06. Following the initial survey, the hole was deepened and, two and a half months later, the company was called out to survey the hole again. “We lowered the gyro to the tie-on point (the final station of the previous survey) and began surveying from 1,300 meters. When we retrieved the data from the gyro, the tie-on inclination was 7.38 degrees and the azimuth was 212.16. We couldn’t believe the incredible repeatability!” says Semadeni.

NORTH-SEEKING GYROThe North-seeking GyroTracer uses the latest gyroscopic and quartz technologies,

along with many advanced sensors, to find direction. It’s a North-seeking gyro; all azi-muth measurements are in reference to geographic north, which means it produces more accurate and precise results because magnetic north shifts its geographic position over time, whereas the geographic north remains static.

NO MAGNETIC INTERFERENCEUnlike other downhole survey or magnetic tools, the GyroTracer it is not affected

by magnetic interference and can be run inside casing, drill pipe and magnetically-dis-

FEATURES / 12)2*!,)(%!(*(42 mm. !

Memory mode allows for mobilization at sites with limited access or where equip- !

ment is not feasible to use.

Wireline mode allows for real-time data acquisition. !

25,000 hour lifetime. !

Uses gyroscopic and quartz technologies. !

K-'.*4+ #%1':-&&$A$ 8+-)$+' 42 .. !

O')$4' 1 '14$&$.&$. +*:-.* 8$91$/@*4 -#8$/09$1'40 8+-)$+ &' 8/$C'(%'B !

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P#8$/09;<4#@ A-+$#%$8-=*#%-* - %1'+?*1"* 4*B&$/$A--. !

“The North-seeking Gyroscopic Inclinometer, which has wireline and memory capability, uses gyroscopic and quartz technologies, along with many advanced sensors, does not require field calibration”«C#"*12*.#-&12#: #'2/#'*4&6" 1 DEC, "3$*-63BF#: 232 ( 3(6*'*4'*4 "&=#4&, 632 # 1 7&*-5#0#-&12#4 23$&/&4, #1.*/;0%BF#: 7#"*12*-.#-&12#& # 2(3">&(,& 6&)'*/*7## ( 1*-&63'## 1 %1*(&"A&'16(*(3'',4# +36-#234#, '& '%=+3&618 ( .*(&"*-'*: 23/#$"*(2&»

Page 73: Oil&Gas Eurasia July-August 2011

7171!"#$% & '()!"#$%&'

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turbed ground. As a consequence, SPT believes the directional survey data it gener-ates is more reliable and accurate than data generated by competing gyros based on MicroElectroMechanical Systems (MEMS).

“When you are conducting exploration work, the technology you deploy in drill hole surveying systems, particularly in demanding environments where wells and holes must be drilled to greater depths with more complex trajectories, you need technology that is highly reliable and accurate,” says Orlando Ramirez, SPT’s CEO. “Unreliable directional survey data can miss targets at great cost, and may also cause environmental damage in sensitive areas such as offshore oil and gas fields.”

RELIABILITYThe North-seeking GyroTracer instrument is rugged, user-friendly, and does not

require field calibration or a roll test before operation. It’s low-power, lightweight and capable of operating on a wireline or battery-operated memory mode. It’s also less expensive than many of the other survey tools and services available.

International Directional Services, a directional-drilling and borehole-survey service company, has tested many survey instruments, both magnetic and non-magnetic, over the years. General Manager Greg Taylor says the company’s experience with the repeat-ability and accuracy of SPT’s new system to date has been “excellent.”

Similarly, positive feedback has come from mining companies in Ontario’s Sudbury Nickel Basin, from Goldcorp’s Red Lake gold camp, from petroleum companies in Tunisia, from the offshore gas fields of eastern Italy, and from other international drilling companies servicing the resource sector.

CUSTOMER AND OPERATOR TRAINING“At SPT, we are committed to the success of our customers,” Ramirez continues.

“We invest 25 percent of all we make back into research and development, focusing both on new product advancement and on implementing upgrades and improvements to existing tools and software. Our focus is 100 percent on delivering technology to enable our customers to meet their specific project goals and objectives.”

But tools are never enough, and SPT does not believe its products alone differenti-ate the company from its competition. What makes SPT successful is its tools in combi-nation with comprehensive and relevant customer and operator training to ensure max-imum efficiency in operation. SPT training and technical teams are on the road through-out the year, delivering theoretical and practical training, along with post-sales technical support, to SPT customers for the life of the equipment they purchase. In an economy where every penny counts, and return on investment is a critical element of any business decision, knowing you’ve got the best tool, and the best service and support team on your side, can make all the difference.

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BENEFITS / +),(/3:,%!42Option for battery or wireline mode. !

The gyroscope is 70 percent more cost efficient than the other survey tools !

and services available.Takes independent surveys to eliminate drifting over depth and time. !

No field calibration required. !

Easy-to-use application and software interface means gyro-calibration can !

be easily performed by the customer.No surface reference points needed and no gyro drift over time. !

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Page 74: Oil&Gas Eurasia July-August 2011

7272 Oil&GasEURASIA

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INFORMATION SYSTEMS INFORMATION SYSTEMS ADVERTORIAL SECTION

One of the most common reasons for purchasing laboratory information manage-ment systems (LIMS) is the ability to integrate laboratory tools and corporate information systems to streamline information management. Despite the fact

that this integration is required by many laboratories, in practice this goal is not always successfully achieved. The results of various studies illustrate a certain gap between expectations from integration and reality. This is because of the complexity of interfac-ing various software, while the direct integration of LIMS with lab instruments saves pre-cious time, and eliminates the possibility of typing errors in results often present in data entered manually. These benefits are especially illustrative when applying gas chromato-graphs, which generate a significant portion of laboratory data.

In fact the only reason separating chromatographs from the LIMS are the various lev-els of laboratory processes. A lack of unification leads to the necessity of market avail-ability of the systems allowing companies to fully integrate data from various instru-ments into a single LIMS system to optimize data management. One of the key challeng-es facing today’s laboratories is to turn a huge amount of laboratory data into a single system, allowing experts to make prompt and reliable decisions. A variety of software solutions at every enterprise leads to generation of huge amounts of disparate data, so that to find the needed information is a challenge.

Many companies use inefficient procedures of data processing, performed manual-ly, using both structured and unstructured data sets. It is often difficult to generate the desired form of a report or document from such a flow of information. In addition, the data formats are often incompatible with each other, which complicates the integration process when a manager is responsible for several different departments or laboratory processes. All of these factors erect barriers to expediting the decision making process and increasing the return on investment.

Full integration of LIMS and chromatography software is an evolutionary step towards the integration and management of laboratory data. This will reduce the cost of imple-mentation, validation, maintenance and training compared to one-off solutions.The goals of increasing productivity can be also achieved by using a unified system of reports generation. The properly designed system of the LIMS integration and chromatography data will provide access to information of various levels, using an intuitive and friendly user interface and will also allow the user to automate the flow of requests from the LIMS to the chromatograph and obtaining results from chromatographs to the LIMS.

For a large scale enterprise, it is essential to arrange production in line with the ERP system planning. This requires a complex sequence of manufacturing operations with-in the framework of the object-oriented systems such as LIMS and MES, in addition to update of the product technical characteristics, determining the output volumes, etc. Availability of the sub-systems integration means a seamless planning for all stages of production. This ensures consistency of all stages of the process, as well as compliance with production and maintenance of the required product quality.

Natalya Pupkova !"#$%&' (')'*+,

Page 75: Oil&Gas Eurasia July-August 2011

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O$B%3 ('+$&(3, 7,* (.+$,)% -+(3/E)*##(,.% ,.$)B%7$8.,2 , #*('0("%3(,.@8 %#.*-A+$5%% %#4(+3$5%% 7#6.+% -+(%&7(",.7$. F*E*#%*3 >.(C &$"$1% &$#%3$8.,2 3#(A%* (+A$#%&$5%% % +$&+$'(.1%B% -+(A+$33#(A( ('*,-*1*#%2. !"#%3 %& -6.*C +*E*#%2 6-(-32#6.(C &$"$1% 27)2*.,2 ,*+7%,#(-(+%*#.%+(7$##$2 $+0%.*B.6+$, B(.(+68 %,-()@&6*. 7 ,7(%0 +$&+$'(.B$0 Thermo Fisher Scientific. G+*%369*,.7$ "$##(A( +*E*#%2 7B)81$-8., 7 .(3 1%,)*, ('3*# %#4(+3$5%*C ,-*5%$)%&%+(7$##/0 -+%)(?*#%C. M)2 +*$)%&$-5%% >.(A( +*E*#%2 Thermo Fisher Scientific -+%3*#2*. Web-,*+7%,/ , 6#%4%5%+(7$##/-3% -+(.(B()$3%, 1.( -(&7()2*. :;<=-,%,.*3$3 -()61$.@ "(,.6- B .$B%3 -+%)(?*#%23, B$B Microsoft, Biz Talk % Share Point.

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G*+*0(" )$'(+$.(+%C B -+%3*#*#%8 ,%,.*3, %#.*A+%+689%0 7,* -+*"-+%2.%2, -(&7(-)2*. '()** >44*B.%7#( %,-()@&(7$.@ "$##/* ")2 6-+$7)*#%2 +6.%##/3% -+(5*,,$3% )$'(+$.(+%%.

M)2 +6B(7("%.*)*C '()** 7/,(B(A( 6+(7#2 >.( – 7(&3(?#(,.@ (-*+$.%7#( -+%#%-3$.@ +*E*#%2, (,#(7$##/* #$ "(,.(7*+#(C ('N*B.%7#(C %#4(+3$5%%, -()61$*3(C 7 +*?%3* +*$)@#(A( 7+*3*#%. G("('#$2 %#.*A+$5%2 -+*7+$9$*. +$&+(&#*##/* %,.(1#%-B% "$##/0 7 A)6'(B(* &#$#%* "*2.*)@#(,.% -+*"-+%2.%2 % -(&7()2*. '()** >44*B.%7-#( 7*,.% '%&#*,.

M)2 -+*"-+%2.%C F(,,%% % ,.+$# =DP ,%,.*3$ SampleManager LIMS -(,.$7)2*.,2 7 +6,,B(2&/1#(C 7*+,%% (. B(3-$#%% !!! «;-*+%(# =%,.*3, ;#?%#%+%#A (F6,)», (4%5%-$)@#(A( -$+.#*+$ Thermo Scientific 7 +*A%(#$0.

G( 7,*3 7(-+(,$3 7/ 3(?*.* ('+$9$.@,2 B ,-*5%$)%,.6 B(3-$#%% !!! «;-*+%(# =%,.*3, ;#?%#%+%#A (F6,)» D$.$)@* G6-B(7(C -( .*)*4(#6 +7 495 504 04 77 %)% -( >)*B.+(##(C -(1.* [email protected].

Once the ERP changes the requirements for productive activity, the LIMS resched-ules the testing, sampling, specifications accordingly, and the staff can immediately start working on the new scheme. In addition, the system does not duplicate data in what is another advantage of working in a single integrated production environment. This approach is not one-way for the transfer of data from the ERP system. Since the ERP systems do not require a detailed laboratory data, the LIMS provides key data in the ERP about the research findings. In most companies, the quality results assurance is super-vised by a quality control division. As a rule, the employees of this department are using the integrated system.

Vital role is played by the manufacturing process information accessibility, it allows for more efficient control of production, providing the timely corrective actions. Timely access to production data is a vital task to prevent loss of production and release of defective products, likely to result in economic losses.

In addition, the analyzers used for rapid analysis are purchased for immediate collec-tion of data, especially if the content of any part is critical. In these cases, if the operator receives information with a considerable delay, there is no sense in obtaining the data at all, as they are needed only in the online mode. Consequently, data access in real time mode is an important need for the laboratories, whereby a direct interface between the MES and LIMS allows the production services to monitor the results of research on-line and make quick decisions.

Thus it is clear that all industries face the need to integrate information within pro-duction facilities. This is a challenge being addressed by many organizations and soft-ware developers. One solution to this problem is the service-oriented architecture used by Thermo Fisher Scientific in its developments. The solution advantages include the ability to communicate some specialized applications. To implement a solution like this, Thermo Fisher Scientific uses Web-services with standardized protocols; this allows LIMS systems access to applications such as Microsoft, Biz Talk and Share Point.

The world of information systems for laboratories is moving forward, and because all laboratories are looking for ways to integrate all information flows into a single flow, scattered systems are not the perfect solution for the laboratories. Thermo Fisher Scientific offers the most advanced solutions for seamless integration of LIMS with ana-lytical tools, as well as MES and ERP solutions. The transition of laboratories to the use of the systems that integrate all companies will provide a more effective use of data to manage the routine lab processes.

For higher-level managers, this is a capability of prompt decision making based on reliable objective information gathered online. This kind of integration transforms the disparate data sources into a deep knowledge of the company operation allowing the users a more efficient business.

For companies in Russia and the CIS system, the SampleManager LIMS is available in the Russian version from the Hyperion Systems Engineering (Rus) Company, an official partner of Thermo Scientific in the regions.

Please do not hesitate to contact Natalia Pupkova, the expert of the Hyperion Systems Engineering (Rus). She is available at +7 495 504 04 77 or can be emailed at [email protected].

Fig. 1. Solution for seam- !

less integration of enter-prise systems offered by Thermo Fisher Scienitic.

!"#. 1. !$%$&"$ '( !

)$#%(*&(+ "&,$-./0"" 1(.'(./,"*&23 #"#,$4 (, Thermo Fisher Scienitic.

Page 76: Oil&Gas Eurasia July-August 2011

7474 Oil&GasEURASIA

Funing Hongda Petrochemical Machinery Co.Presents Innovative Technical Equipment for Russian Oil&Gas Sector

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DOWNHOLE TOOLSDOWNHOLE TOOLSADVERTORIAL SECTION

Funing Hongda Petrochemical Machinery Co., Ltd, was founded in1979, with 30 years experience in

researching, developping and producing downhole tools. We are committed to pro-viding customers with the best downhole operation services using economic and effi-cient means.

We strictly implement the requirements of ISO9001 and API quality management system to ensure that our products and ser-vices meet customers’ requirements. At the same time, we can manufacture down-hole operation tool according to customers’ requirements. Today, our customers work all over the oil fields in China.

Now, we are sincerely willing to cooperate with you and provide you with more choices.

Retrievable Bridge PlugRetrievable bridge plug is a downhole

plugging tool used in oilfields, which consists of setting mechanism, anchoring mech-anism and sealing mechanism etc. With unique self-locking structure and reliable two-way pressure bearing capacity, it can ensure reliable sealing without the need to use an overlying mortar surface. The retrievable bridge plug is set by cable setting tools or

Type / H'$O.D., mmA%407&*3 /'%#124, ##

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HDQSA-73-35 73 635 35 120/150 14~16 20~40 80~82

HDQSA-76-35 76 695 35 120/150 14~16 20~40 82~86

HDQSA-80-35 80 810 35 120/150 14~16 20~40 86~90

HDQSA-92-70 92 930 70 120/150 16~18 30~50 98~102

HDQSA-96-70 96 930 70 120/150 16~18 30~50 102~106

HDQSA-100-70 100 930 70 120/150 16~18 30~50 106~110

HDQSA-110-50 110 640 50 120/150 16~18 30~50 118.6~121.4

HDQSA-114-50 114 640 50 120/150 16~18 30~50 121.4~124.3

HDQSA-114-70 114 815 70 120/150 16~18 30~50 121.4~124.3

HDQSA-148-50 148 680 50 120/150 18~20 40~60 154.8~159.4

HDQSA-150-50 150 680 50 120/150 18~20 40~60 157.1~161.7

HDQSA-210-35 210 1160 35 120/150 12~15 50~80 222.4~224.4

This article was supplied courtesy of the Funing Hongda Petrochemical Machinery Co., Ltd

!"#"$% &'()*+"#,-(.# /*0&#.1(2 Funing Hongda Petrochemical Machinery Co., Ltd

Gu Zheng da, !

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Page 77: Oil&Gas Eurasia July-August 2011

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hydraulic setting tools. When necessary, it can be released and recovered. After wear-ing parts are changed, it can be still re-utilized downhole. The retrievable bridge plug can be used in cooperation with downhole tools for temporary plugging and selective plug-ging etc. It can be extensively used in production test, workover, testing and hydrocar-bon reservoir improvement etc., and is a safe, reliable and cost effective full-function downhole plugging tool.

AdvantageReliable anti-sticking design: the slips use a built-in slip structure, so that the bridge

plug is not easily blocked and stuck when pulled and lowered in the well bore and can be used safely in the well of any obliquity.

Flexible setting mode: the bridge plug can be sent in well and set by the cable setting tool or the hydraulic setting tool, and it is only required to select corresponding setting tool based on specific well conditions.

Unique anchoring mechanism: by flexibly combining the slips, slip cone and the outer barrel of the slips, the bridge plug has good two-way pressure bearing capacity and is applicable to the casing of various grades.

Notice:Casing of setting section should be without serious corrosion, breakage or seri- !

ous deformation.Drift and scrape the well bore, and wash out the dirt and dead oil before RIH. !

Control the RIH velocity in 30 tubings/hour. !

Control the blockage force within 30 KN during RIH. !

Run the releasing tool to 3-5 meters from the bridge plug surface, then clean the !

well completely.To prevent falling into the well during POOH, avoid revolving of the pipe string. !

Retrievable Bridge Plug for Cement SqueezingRetrievable bridge plug for cement squeezing is a downhole cement squeezing and

plugging tool used in oilfields. It consists mostly of setting mechanism, anchoring mech-anism, sealing mechanism, and sliding sleeve switching mechanism, etc. The retriev-able bridge plug for cement squeezing is set by cable setting tools or hydraulic setting tools. After cement squeezing, it can be released and recovered. After wearing parts are changed, it can be still reutilized downhole.

Notice:The cautions of RIH, Setting and POOH: please refer to the retrievable bridge !

plug.After completing cement squeezing operation, lift the pipe string by 2-3 meters !

and reverse well cleanout for over a cycle till fresh water passes in and out with large displacement.

During transport and handling, avoid colliding and getting wet. !

Store away from heat, not allow to contact acid, alkali and salt, etc. !

Type / H'$

O.D.,mm

A%407&*3 /'%#124,

##

Length, mm

I+'&%,##

Operating pressure differential,

MPaJ4%/'1&2 4%)"91."

/%-+1&'(,8F%

Operatingtemperature, C

K%)"9%( 21#$14%204%, °C

Releasing load, kNA%.4056% $4'

-*,-")"7/1&'',6A

Applicable casing I.D., mm

F4'#1&'#*3 -&0241&&'3 /'%#124 "),%/&"3 6"+"&&*,

##

HDQSC-110-50 110 990 50 120/150 60-80 118.6-121.4

HDQSC-114-50 114 990 50 120/150 60-80 121.4-124.3

HDQSC-148-50 148 1130 50 120/150 80-100 154.8-161.7

HDQSC-210-35 210 1450 35 120/150 100-120 222.4-224.4

!

2,!

!

Funing Hongda Petrochemical Machinery Co., Ltd.

Add: NO.66 Chenghe East Road, Funing, Jiangsu, P.R.China 224400

Tel: 0086-515-87212179

Fax: 0086-515-87266187

Web: http://www.cnhdm.com

E-mail: [email protected]

Page 78: Oil&Gas Eurasia July-August 2011

7676 Oil&GasEURASIA

Advanced Offshore Sakhalin Development Technology!"#$%&%''(% )%*'"+",-- ".#"%'-/ !0*0+-'.1"," 2%+340

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ENGINEERING SURVEYSENGINEERING SURVEYSADVERTORIAL SECTION

One of the key structures of the Sakhalin-3 project is the Kirinskoye gas condensate field, located in the

Okhotsk Sea 28 kilometers east of Sakhalin and 15 kilometers east of Lunskoye deposit.

The subsea section of gas transportation link between the Kirinskoye and the coast is a part of a general-purpose gas main which feeds the hydrocarbons from the deposit to the Sakhalin – Khabarovsk – Vladivostok gas pipeline, and which will become in the future a part of a unified gas transportation system in Siberia and the Far East.

The difficult conditions of this Sakhalin field required selection of appropriate advanced upstream technologies. Gas and condensate production is guaranteed by a unique underwater equipment and technol-ogy that is new to Russia.

Doing their part on the design of Kirinskoye subsea production complex, experts of Piter Gaz company examined the existing technologies and engineer-ing solutions for offshore development. Comprehensive engineering surveys on the “Kirinskoye GKM” project were run during the 2010 navigation period.

Piter Gaz developed the optimal produc-tion engineering research program for get-ting the processed data needed for decision-making in both intermediate and final stag-es of the project, with due consideration to the difficult climatic and geotechnical condi-tions (abrupt changes in weather, speed and direction of currents, frequent storms).

On the first stage the company performed hydrographical and geophysical works, including shooting with MBES and SSS, SPB, allowing to estimate soil foundation structure and volume of geotechnical work (drilling, sampling of bottom sediments, and the number of static probing points). The experts used the obtained data to set up a composite map-case.

A fragment of the bathymetric survey and a shadow sea- !

bed model.!"#$%&'( )#(*%&("*+&,-./ ,0&%-* * (&'&1./ %.2&3* !

"&34&5# %.",-.$. 2'#.

A fragment of sonar image of the seabed. !

!"#$%&'( ,.'#"'.$. *6.)"#7&'*8 %.",-.$. 2'#. !

This article was supplied courtesy of Piter Gaz Company !"#"$% &'()*+"#,-(.# /// «01"(' 2#3»

Page 79: Oil&Gas Eurasia July-August 2011

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J'1(2:( #*;'-: 0#'2',"1"%? 2 0(#"-', % &'$B* "@$9 0' $'9;#? 2010 )',*. D #(+51?-*-( +* &'#'-&"> $*2")*B"'$$:> 0(#"', ;:1 2:0'1$($ 0'1$:> &'.01(&% "$/($(#$:4 "+:%&*$">, ,'%-*-'7$:> ,19 0#"$9-"9 0#'(&-$:4 #(E($"> &*& $* %-*,"" «J#'(&-$*9 ,'&5.($-*B"9», -*& " $* %-*,"" «H*;'7*9 ,'&5.($-*B"9».

O$'%-#*$$:. 0*#-$(#'., #*+#*;'--7"&'. ';'#5,'2*$"9 ,19 0',2',$')' ,';:7$')' &'.01(&%*, %-*1* $'#2(/%&*9 &'.0*$"9 FMC Kongsberg Subsea AS.

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– 28 &..

J1*$"#5(-%9, 7-' 22', ,*$$')' .(%-'-#'/,($"9 2 #*+#*;'-&5 2$(%(- %2'> 2&1*, 2 %'+,*$"( ;1*)'0#"9-$:4 5%1'-2"> ,19 )*+"G"&*B"" F*1?$()' D'%-'&* H'%%"" " '#)*$"+*B"" 0'%-*2'& 0#"-#',$')' )*+* " &'$,($%*-* $* ."#'2'> #:$'&.

Data evaluation revealed a close-to-surface segment of the gas layer which represented a significant threat to the mani-fold installation zone both in terms of aggressive environ-ment (considering construction materials) and due to the poten-tial soil liquefaction during the seismic load.

This discovery led to a deci-sion to shift the manifold instal-lation platform 250 meters.

Also, the data collected dur-ing the first stage led to a deci-sion to drill extra wells on the route of gas pipeline and flexi-ble drill string as in-depth anal-ysis indicated soil base out-breaks. These drilling opera-tions enabled estimating the volume of seabed works and number of sites involved.

Subsequent stages provided detailed data that ensured a full assessment of the structure and foundation bed properties.

The field work was run from late June to November 2010. As a result, within the short naviga-tion period the company com-pleted a full range of engineer-ing research, sufficient for mak-ing both project documentation and detailed documentation.

The work was made easier by Norway-based FMC Kongsberg Subsea AS, a foreign partner and the developer of equipment for the subsea production facility.

The Kirinskoye subsea pro-duction site includes six wells with seabottom wellhead loca-tion, a system of infield pipelines and flexible drill strings, mono-ethylene-glycol supply line, gathering manifold, gas main and onshore control instrumen-tation for the subsea produc-tion facility. The total length of the infield pipelines from wells to the manifold is 14.3 kilome-ters; the subsea link runs for 28 kilometers, transporting gas condensate mix from the field to the onshore complex gas treat-ment facility.

Putting the field online will contribute to creating favorable conditions for the gasification of the Russian Far East and deliv-ery of natural gas and conden-sate to the global markets.

A fragment of the seismic-sonar profile. !

!"#$%&'( ,&/,%.#-9,(*+&,-.$. :".5*38. !

The gas zone at the manifold installation site. !

;#6.1#8 6.'# 1 "#/.'& :.,(#'.1-* :3.<#2-* %#'*5.342#. !

A fragment of soil base outbreak (30 meters sea depth.) !

!"#$%&'( 1=>.2# $"9'(.1 -."&''.$. .,'.1#'*8 ($39)*'# %."8 30 %). !

Page 80: Oil&Gas Eurasia July-August 2011
Page 81: Oil&Gas Eurasia July-August 2011
Page 82: Oil&Gas Eurasia July-August 2011

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F&2,2# /7.42( & .4+ %&'()# – :&+#2,2# +4<2 www.oilandgaseurasia.com !

Page 83: Oil&Gas Eurasia July-August 2011
Page 84: Oil&Gas Eurasia July-August 2011

!"#$!"#"$ %"&"'$!($)*+"#,-./0!&"#.$+((

«STALINGRAD»

400075, !. "#$!#!%&', (#))* +,-&.#%#,, 16

/*$*0#1: (8442) 53-02-20, 53-04-40

2&3): (8442) 35-85-11, 53-02-01

E-mail: [email protected]&5.: www.vzbt.ru

TECHNOLOGY, PROJECTS & TRENDS IN RUSSIA & CIS - UPSTREAM, DOWNSTREAM, PIPELINES, OF

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