Offshore Production Facilities

8/9/2019 Offshore Production Facilities

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&ei#!l, Nor6( (Fixed Platform)

The Heimdal gas field is located in the Norwegian sector of the central North Sea. Water depth inthe area is almost 400 feet. The field has been developed with an integrated drilling, production andaccommodation facility with a steel ac!et "H#$%&. ' $() for Heimdal *as +entre "H*S& was approvedin anuary %---. This included a new riser facility "H$&, connected by a bridge to H#$%. Heimdal is now

mainly a processing centre for other fields. 'tla, Huldra, S!irne and /ale deliver gas to Heimdal. The fieldhas been recovered by pressure depletion. Heimdal will continue to produce small amounts of gas until0%4.

The subsea facilities at Total1s 'tla gas condensate field are now on stream. 'tla was developedsubsea with a tiebac! to e2isting infrastructure between the S!irne development and Heimdal productionplatform. 3n 0% the field is e2pected to flow gas at an average rate of %4,000 boed and condensate at,500 bcpd. The fast6trac! proect was brought on line within the planned schedule and budget two yearsafter completion of e2ploration drilling. The field is located in production license %0+ and sits in -0 feetof water.

The %.4 billion cubic meter6'tla gas and condensate field is e2pected to be brought on line in thefirst half of )ctober according to Total, the field operator. 'tla will be utili7ed via a subsea template tiedbac! to an e2isting pipeline between the S!irne subsea facilities and the Heimdal *as +enter. The

original e2ploration well was drilled into the 8rent formation and is now being re6used as a productionwell.

2urchison, Nor6( (Fixed Platform)

The #urchison field is located in the Northern North Sea 8loc! %%9%-, north of 'berdeen in the:ast Shetland 8asin, straddling the ;nited bopd. 3t1s estimated that about 400 million barrels of oil have beenproduced from the field1s -> development wells with an impressive recovery rate of over 50?. +N too!over operatorship in 00 and e2tended the commercial life of the field by %0 years. Now, the companywill move forward with an innovative decommissioning program that will see the infrastructure at#urchison completely removed by 0%-.

Sngu, Bngl!esh (Fixed Platform)

+onsidered the first offshore gas field development in 8angladesh, the Sangu field is located in8loc! %@ in the 8ay of 8engal about > miles "45 !ilometers& southwest of +hittagong. Santos operatesthe bloc! with a =5 percent interest. Halliburton holds the remaining sta!e. (iscovered in %--@, the fieldwas brought on stream in %-->. The field is currently in production with nine development wells tied6bac!to the Sangu6' platform. :stimated to hold contingent reserves of 0 8cf, the Sangu field is currently indecline. 3n order to e2tend the life of the field, the operator set out to drill on infill development well fromthe Sangu platform, Sangu6%%, and one appraisal well over N: Sangu. 3n 0%, the operator found a newgas reservoir through well Sangu6%% in the Sangu area with about @@ feet "0 meters& of good6Auality gas


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pay. The well will be completed and tied into the Sangu facilities. The South Sangu field, discovered in000, is located about miles "4.> !ilometers& southeast of the Sangu6' platform. There are currentlythree wells on the field, which has a contingent resource of 5% 8cf. (ue to a steady decline in gasproduction throughout 0% the decision was made to halt operations at Sangu. 's part of the $roductionSharing contract the field facilities will be handed over to $etrobangla.

Santos has found a new gas reservoir through well Sangu6%% in the Sangu area with about @@feet "0 meters& of good6Auality gas pay. The well will be completed and tied into the Sangu facilities. Theoperator is continuing to assess the volumes and flow potential of the reservoir. 'fter completing Sangu6%%, the Seadrill ac!up )ffshore esolute "50B 3C+& will be demobili7ed. Sangu6%% was the final well in athree6well drilling campaign in 8loc! %@ $S+ that commenced in September 0%%. The first well, SouthSangu64, found gas in one target but was unable to add further reserves due to encounteringanomalously high formation pressure, and had to be abandoned prior to reaching its primary obective.The second well, N: Sangu6% drilled in (ecember 0%%, failed to encounter commercial hydrocarbonsand was also abandoned

7i4o#b, Bloc8 1+, Angol (FPSO)

Situated roughly -0 miles "%45 !ilometers& off the coast of 'ngola is 8loc! %5, featuring the>,4 acres "4,000 sAuare !ilometers&. 3t is estimated the bloc! containsmore than .5 billion barrels of recoverable reserves, and cumulative production of the bloc! hassurpassed one billion barrels.

:22on#obil was awarded operatorship of 8loc! %5 in %--4 and the first discovery was made in%-->. 's operator, :22on#obil holds a 40? interest in the bloc!D :ni holds 0?D 8$ holds @.@=?D andStatoil holds the remaining %.?.

The development of 8loc! %5 was divided into three phasesD $hases ' and 8 commencedproduction in 'ugust 004 and uly 005, respectively. $hase +, $hase 3 started production in anuary00>, and $hase +, $hase 33 came online in uly 00>.

3n (ecember 00, :sso1s Ei!omba field became the first of three fields to come on stream in offshore'ngola 8loc! %5, about 0 miles "=0 !ilometers& northwest of 'ngola1s capitol Cuanda. The field wasdiscovered in %--- in a water depth of 4,>5@ feet "%,4>0 meters&. Ei!omba holds an estimated %00 millionbarrels of recoverable reserves with crude production rates of >0,000 bopd.

'long with the operator :sso, holding a 40? interest, other participants in 8loc! %5 are 8$ :2plorationwith @.@=?, 'gip 'ngola :2ploration with 0?, and Statoil with a %.? interest.

Xikomba DevelopmentEi!omba uses an :arly $roduction System ":$S& that consists of nine subsea wells "four

production, four water inection and one gas inection&, :22on#obil1s third deployment of its :$Stechnology offshore West 'frica and the first '$S offshore 'ngola. These wells tie6bac! to the leasedEi!omba F$S).

:sso :2ploration awarded a development contract to Technip6+ofle2ip, including procurement, fabricationand installation of fle2ible flow lines and risers, connecting them to an F$S). The contract also includedinstallations of the umbilicals, rigid umpers and associated subsea eAuipment for the field.


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(ubai (rydoc!s of ;': converted the very large crude carrier "/C++& #osocean to the Ei!omba F$S)in 'ugust 00. Weighing in at 5=,000 tons ",%4@ tonnes&, the F$S) can store up to %.> ##bo andhas a pea! daily production rate of -0,000 barrels.

Technip6+ofle2ip was in charge of the proect management, engineering, procurement, transportand installation of the production lines, water and gas inection lines and Flowline :nd Terminations"F:T&. The +S) +onstructor performed the installation campaign during the second half of 00.

+oming on stream in (ecember 00, Ei!omba is the deepest F$S) ever installed using fle2iblerisers in West 'frican waters.

Kizomba A

The G billion , while the other two fields, Sa2i and 8atuAue, started production in 'ugust00>. The


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Shelle(, U7 (FPSO)

Cocated on 8loc! 9 in the ;< +entral North Sea, roughly %%- miles "%- !ilometers& east ofFraserburgh, Scotland, is the Shelley oil field. Wholly owned and operated by )ile2co, Shelley hasestimated recoverable reserves of - ##bo.

3n %->4, well 96, was discovered then plugged for two decades, until it was awarded to)ile2co in 005. 3n )ctober 00=, the )cean *uardian semisubmersible drilled eight well penetrationsfrom a single subsea well bore to appraise the Shelley discovery.

Then, several appraisal wells were drilled to further define the area. The appraisal well 9b6% reacheda true vertical depth of %,>50 feet "4,% meters&. 3t tested at a rate of ,0> bopd at more than %degrees '$3, located within sands from the $aleocene Forties age. The well successfully defined a broadlow relief oil6bearing structure. ' second appraisal drilling was conducted on well 9b6% to determinethe si7e of the reservoir, which measures %,=0 acres "= sAuare !ilometers&.

The last appraisal well, 9b6%t, was tested through 4 feet "% meters& of perforations representing %>true vertical feet "5 true vertical meters& of perforated reservoir from the top of 4 vertical feet "%0 verticalmeters& of oil pay. The 9b6%t appraisal well tested at a flow rate of ,0> bopd at a @9@46inch cho!e.The findings confirmed the previous discovery from the 9b6% well.

Field Development

3n 00>, the Sedco =% semisub began Shelley1s development drilling. The field consists of threesubsea wells tied6bac! to a central manifold and a %6mile "6!ilometer&, >6inch6diameter pipelineconnected to the Sevan /oyager, a cylindrical type Sevan 00 F$S). ' water disposal9inection pipelinewill also be installed from the F$S) to the Shelley drill center. The wells and infrastructure will bemonitored, controlled and operated from the F$S).

3n 00>, Technip was awarded a ;S G4 million ":; %-0 million& contract for the engineering,installation and commissioning of pipelines for the Shelley field. The contract covers the control umbilicalsand umper, the fle2ible risers, the subsea manifold and an attendant f lowline.

Sevan #arine 'S built and owns the Sevan /oyageur F$S). )ile2co operates the leased F$S) for afi2ed6term of five years, with e2tension options for an additional five years at a contract value of G=0million.

The Sevan /oyageur F$S) is %= feet "@@ meters& long and %-= feet "@0 meters& wide, with adisplacement of 55,000 tons "50,000 tonnes&. Sevan /oyageur has a production capacity of 5,000 bopdand 0 ##cf9d ".@ ##cm9d&, and a storage capacity of 00,000 barrels of oil. 8ased on Sevan #arine1sproprietary technology, the cylindrical F$S) can operate more efficiently in harsher climates on small tolarge fields because of its fle2ible design and motion characteristics. The round6shaped vessel has lesshull surface, which reduces the amount of steel needed for construction, but contains the same storagevolume of traditional F$S)s.

8uilt at the Iantai affles Shipyard in +hina, the Sevan /oyageur was transported to a :uropean

shipyard for topside hoo!6up and commissioning in the last Auarter of 00=.

3n November 00>, the F$S) arrived on the Shelley field to be installed and hoo!ed up to a pre6laidmooring system.

$roduction commenced on 'ug. @, 00-. With a life e2pectancy of 5 years, Shelley is e2pected to pea!at 5,000 bopd. $roduced oil will be offloaded to shuttle tan!ers then transported onshore.

The field ceased producing on uly %4, 0%0 and was decommissioned.

A4urite, Congo (FPSO)

The $ride South $acific semisub discovered the '7urite field, located on the #er $rofonde Sud8loc!, offshore epublic of the +ongo. #urphy )il serves as the operator and has a 50? wor!inginterestD $' esources '8 holds 5? interestD and SN$+ holds the remaining %5? interest.

3n anuary 005, the '7urite #arine No. % discovery well was drilled in 4,5% feet "%,>% meters& of waterand found a significant amount of oil pay in multiple reservoirs of Cower #iocene age. 'n appraisal well,

'7urite #arine No. , was drilled in 4,4>> feet "%,@> meters& of water and confirmed the previous oil payfinding. ' subseAuent flow test from one 7one produced >,000 bopd and 4.@ ##cf9d "%%,%0= #cm9d&.


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Offshore Production Facilities

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