Well Integrity & Production Enhancement using an Integrated LWIV West African Case Study
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1 Well Integrity & Production Enhancement using an Integrated LWIV West African Case Study Ekene Ogbechie Business Development Manager
2 Agenda Campaign Overview Drivers & Objectives Location Vessels & Intervention Systems Well Enhancer / Skandi Contractor SIL Project Challenges & Solutions Planning, System Integration & Logistics In-field Operations Campaign Summary
3 Campaign Overview 2012 & 2014 Drivers & Objectives Helix Well Ops was contracted to undertake a 60+/- day program offshore Bioko Island, Equatorial Guinea The chosen well-sites within the Field varying, distance wise, from 0.5km to 8km apart, the speed, mobility and operational efficacy of a Helix Well Ops DP3 monohull vessel was the preferred option for the client Transit average speeds of 12knts = optimization of in-field non-operational time spent Well access in under 40 hours (following DP/Marine prep, TC ops, SIL ops) = reduces costs v MODU Reduces need for additional support assets for MODU in-field (stand-by, AHV, supply vessels) = additional costs The key client objectives for Helix Well Ops (Project Team) were to facilitate production gains through XT Change out, gas lift valve (GLV) change-outs, as well as to perform investigative well work and data gathering.
4 Campaign Overview Vessels: Well Enhancer & Skandi Constructor Date: December March 199 days ( ) including Mob to De-mob (UK to UK 3 weeks to/from) 111 days = Light Well Intervention in-field ops 5 days = Transits/port call mid-campaign (fuel, chemical load out, crew changes & mobilize Horizontal XT TRT) Campaign: 13 x subsea wells (7 + 6) 11 x Production vertical XT s 2 x Water Injectors horizontal XT s Work Scope: Various (Well Maintenance / Integrity, Production Enhancement & Data Gathering Trapped annulus mitigation issues XT change-out TC/XT remedial/repair operations Tubing/annulus communication testing GLV change-outs SCSSSV Lock-out Pulsed Neutron Log (reservoir evaluation/monitoring)
5 Campaign Overview - Location Field
6 Active heave-comp Tower, Crane, Riser Handling & Skidding system Accommodation (120) & project offices 1 x WROV 1 x Obs ROV Well Services: Slickline E-line Coiled Tubing Pumping Cementing XT ops Subsea Intervention Lubricator SIL 132m 7 3/8 Subsea Intervention Lubricator Tower Lifting Capacity 150Te Crane 100Te 2 x 10k psi SPM600 pumps Main deck 1 x bulk fluid tank 150m3 (943bbls) Below deck 2 x drill water tanks 90m3 each 1 x bulk fluid tank 190m3
7 WE Aerial view from MPT deck layout/equipment spread SIL Umbilical/reeler Pumps Slickline spread Phase II XT E-line spread Moonpool Looking Aft Looking Fwd
8 WE Vessel deck layout c/w Slickline spread Slickline spread
9 WE Key Equipment SIL & Services Subsea Intervention Lubricator c/w control umbilical in Multi Purpose Tower (MPT) 7 3/8 SIL API and NORSOK spec 10k psi rated 600m capability (extendable) Slickline E-line XT on wire Deployment Recovery Third party Slickline ASEP/A60 unit PEAK tooling Interwell tooling Aker KOT s (Kick Over Tools) E-line winch and logging cab Archer Omega Tractors Halliburton Neutron log H2s Spread Total Safety Cetco Filtration Package Cement spread contingency Pumping spread contingency
10 Accommodation (100) & project offices Active heave-comp Tower & Skidding system Services: Slickline E-line Pumping XT ops deployment/recovery P&A/decommissioning 2 x WROV Main Crane 2009 build/x-bow design Ulstein Norway Transiting speed 12knts. av DP3 full redundancy (engine failure/fire/flood) 7 3/8 Subsea Intervention Lubricator Tower Lifting Capacity 150Te AHC Main Crane 150Te AHC 120m 2 x 10kpsi SPM600 pumps Main deck area 1,470m2 Below deck (fluids storage) 700m3 project specific chemicals 3,150m3 (technical fresh water)
11 Skandi Constructor Back Deck (pre/post equipment) ROV footage 653m w/d SIL/XT ops
12 Skandi Constructor Subsea Intervention Lubricator Subsea Intervention Lubricator (SIL) spec: DNV Certified equipment 7 3/8 ID thru-bore (HXT crown plug access/recovery/sleeve insert) 10k psi working pressure range c (0 250f) temperature range Sour service H2S NACE MR Independent dual power & comms for full redundancy 1500m water depth rated deployment/operational Slickline E-line Trees deployment/recovery High rate pumping capability through SIL main bore 7 3/8 SIL assembly (comprising Stuffing Box/OWL; Riser (lubricator) EDP, LRP & spool connector > client TRT) positioned in the MPT prior to deployment
13 Project Planning Client Corp HQ Helix Well Ops Eur & Afr HQ Client Country ops Superior project planning was required due to the geographic nature of this specific project. 13 The Challenge Field Location: offshore Equatorial Guinea Operator Projects Team: Houston, Texas USA Operations Team Malabo: Equatorial Guinea Helix Well Ops Vessel & Project Team Location: Aberdeen UK The Solution Helix Well Ops dedicated Project Engineering resources from Aberdeen to work with the Client Projects Team in Houston. Key roles included; Prepare all documentation for the campaign (well intervention work) integrated with client/helix safety management systems with client management system 3 rd party well servicing company interface, equipment and management Assist with procurement/manufacture of new subsea equipment/project specific hardware (Horizontal TRT, electrical control umbilicals, etc) Weekly calls were held between the 3 key locations Client/Helix Well Ops drew on their experiences of the 2011/12 campaign, as well as liaising with 3 rd party service providers/suppliers in-country, proved valuable for upfront planning and logistics Additional Helix Well Ops Project Engineers were dedicated to clients onshore support base, to support operations. Daily morning calls; operational calls were coordinated between the UK Helix Well Ops office (Project Management), Vessel (Client, Project Management/Engineers) and Client office in Malabo, EG, across the campaign
14 Well Operations 2012 (3 Phases) Project Details: 7 wells = 66 days (including arrival onsite, well-work, transits) Water depth ranges 423ft 1545ft (128m 468m) Uptime 94.9% Equipment NPT 4.5% Vessel NPT 0% WOW 0.6% Intervention Objectives: GLV change out (Trapped Annulus mitigation & Production Enhancement). Well suspension install permanent Bridge Plug Reconfigure gas lift valves for on-going production enhancement Production Tree (XT) change-out Outcome: Replaced GLV s (9 valves total) Successfully suspended Well Successful tree Changeout retracted flowline and unlocked and recovered XT. Installed and tested new XT A total of 69 wireline runs were conducted
15 Well Operations phases) Project Details: 6 wells = 50 days (arrival onsite, well-work, transits) Water depth ranges 623ft 2142ft (190m 653m) Uptime 98.83% Equipment NPT 1.17% Vessel NPT 0% WOW 0% Intervention Objectives: Investigate TC & XT integrity issues Investigation Tubing Integrity & Replace GLV s Install & test SCSSSV insert Perform Pulsed Neutron Log - Evaluate fluid saturations across reservoir intervals Outcome: Replaced TC couplers reinstate hydraulic control for host facility for XT operations/functioning WROV Troubleshoot XT valve functioning successfully Tubing/Annulus communication tests EV Camera & multi-arm calliper deployed Replaced GLV s (10 off) Successfully installed & tested SCSSSV insert to allow for water Injectivity on previously shut-in well E-line tractor utilised successfully on high-deviation well (93 ) to perform successful Pulsed Neutron Log 1 x well A total of 52 wireline runs were conducted
16 Campaign Summaries Logistical Demands achieved! Planning Houston/Aberdeen Execution Equatorial Guinea Close Out Aberdeen Performance Expectations achieved! ZERO incidents/accidents no harm People/Environment 13 well campaign nearing 100% uptime on in-field ops Client estimate MODU circa days & days LWIV campaign estimate = 66 days & 60 days LWIV campaign actual = 116 days 111 days = Light Well Intervention in-field ops 5 days = Transits/port call mid-campaign UPTIME EQUIPMENT NPT VESSEL NPT WOW Hrs Days % Hrs Days % Hrs Days % Hrs Days % Operational Objectives achieved! Successfully executed following ~8 months extensive planning, meetings & collaboration by international multi-functional teams Increased production through GLV change-outs on wells Increased production by bringing back online 2 x previously shut-in wells SCSSSV Insert (allowing water injection to recommence) Tubing Integrity investigation and Tree Valves troubleshooting First LWI from a mono-hull vessel in Africa Successful crew-changes, post experiences/learnings of 2011/12 campaign via Cameroon Coordinated & operated a multiservice campaign, utilising: Slickline/E-line Pumping/Filtration ROV ops
17 Well Enhancer Vessel Deck Layout with TRT s/xt 7 3/8 SIL Phase II XT TRT on SIL/inspection stand Phase II XT SEA XT TRT SEA XT
18 Well Enhancer ROV screen grab of Tree-cap Operations ROV footage of Tree Cap Recovery Tool (TCRT) deployment phase from the Well Enhancer, and on guide-wires, which are also deployed from the vessel. XT to be intervened on and then changed out TCRT on Guide-wires
19 Skandi Constructor Well Operations SIL c/w FMC Phase I (vertical XT), TRT & recovered Tree Cap SIL c/w FMC SEA (vertical XT) & TRT pre-deployment SIL c/w FMC horizontal & TRT pre-deployment
20 Skandi Constructor Well Operations Equipment Spread 1) SIL Main Umbilical 2) Eline and Slickline Units 3) Pumping Spread 4) Additional Chemicals 5) Kill Hose and 5-core Downline 6) Tractors and Logging Tools 7) Vertical and Horizontal TRT
21 Key Commercial Benefits The Client advised that the Campaign represented an efficiency improvement (cost/time/equipment) against a MODU of +/- 50% Client estimated 13 wells by MODU to take circa 90 days on average 13 wells by a Helix Well Ops LWIV took circa 63 days on average Key benefits: No additional costs. Support vessels, anchor handlers, logistics associated with a MODU Fast mobilisation across the field and from well to well (some well site were 2-8km apart) Fast set-up at wellsite (DP trials 4-6 hours settings/rov site survey) No Rig riser to run or torque deploy SIL through open water, test and proceed with well-works
22 Thank you Follow Helix ESG on Twitter: 30 Years as the Leader in Rigless Subsea Well Intervention Join the discussion on LinkedIn:
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