Engineering services · New line
From reservoir to production: integrated study, candidate screening, well-integrity assurance, intervention design, procurement and workover engineering supervision.
Light and medium crude · Nationwide coverage
Why now
Source: Venezuelan Petroleum Chamber, Venezuela Energética forum (April 2026). Reference figures
An idle well retains its wellbore, cemented casing, location and flowline. With remaining reserves confirmed by material balance and barrier integrity verified, the intervention restores production at a fraction of the CAPEX of a new well, with no exploration risk and a cycle time of weeks.
Reactivating the idle inventory demands reservoir, production and workover engineering backed by operational experience. Rig supply is growing faster than these technical teams: engineering is the program's limiting factor.
Where value is lost
Wells are worked over by rig availability rather than remaining reserves, pressure and drive mechanism. The well ends up reconditioned but not producing.
Hook load and drawworks power below the string weight plus fishing overpull. The string — or the well — is lost.
Casing, cement and wellhead with no prior diagnosis (cement log, pressure test). The problem is found with the rig already on location.
Tubulars, packer or third-party services arriving after rig-up. Non-productive time paid at rig rate.
Tubing, artificial-lift method and perforation defined without modeling the IPR/VLP system. The well produces below its potential.
Field decisions with no approved program or record. No traceability and no lessons learned.
Cost concentrates at the rig; the outcome is decided by the engineering that precedes it.
Technical approach
The well is a continuous hydraulic system from the drainage radius to the separator. Production results from the balance between the reservoir's inflow capacity (IPR) and the lift capacity of the well and its facilities (VLP). Every reactivation decision is made on that integrated model, not on an isolated stage.
ReservoirIPR
Static pressure, remaining reserves, drive mechanism, permeability, formation damage, fluid contacts and PVT. Defines inflow potential: the IPR curve.
WellVLP
Barrier integrity, mechanical diagram, perforated intervals, tubing, packer and artificial-lift method. Defines lift capacity: the VLP curve.
Surface
Wellhead, flowlines, manifolds, separation and backpressure of the gathering system. Sets the wellhead pressure the well must produce against.
Practical consequence: tubing diameter, lift method, the interval to perforate and even rig capacity are outputs of the integrated model, not input assumptions.
Service scope
Each phase closes with a technical report and a client approval to continue, adjust or stop the program. The scope can be contracted in full or by phase.
Phase deliverable Potential report by reservoir and sand, opportunity and current-pressure maps, a validated technical database and an idle-well inventory with preliminary potential.
Phase deliverable Ranked wells with the recommended reactivation sequence. Weighting criteria are agreed with the client.
Phase deliverable A diagnosis sheet per well, the recommended intervention type and wells ruled out with technical basis. Separates wells recoverable without a rig from those needing a full workover.
Phase deliverable A per-well workover program with the rig technical requisition, approved by the client.
Phase deliverable Materials released on location; procurement is closed against the program, not the other way around.
Phase deliverable Supervised execution with change control and daily reporting.
Phase deliverable Initial well test and match against the design, close-out report and program feedback.
Timings are referential (assumes 15–20 rig days and available data). From the second well onward the phases overlap: while one well is on the rig, the next already has an approved program and materials on location.
Client data
We work on whatever data repository the client has, in whatever state it is in. Results are delivered in OSDU- and ArcGIS/QGIS-compatible formats so they integrate into the client's platform with no rework. Platforms organize the information; they don't decide which well to intervene or how. That is our scope.
Engineering and supply
SERCOESCA supplies OCTG tubulars (API 5CT), sucker rods and mechanical-pumping accessories (API 11B/11E), lubricants and location modules. The specification comes out of the design, and procurement is closed against the program — not the other way around.
Technical governance
We own no rig and operate no equipment. The technical requisition is issued from the well's loads and pressures; the client contracts the rig and the contractor is responsible for the operation.
No operation runs without an approved program; every deviation is documented and authorized before execution.
We verify two barriers throughout the intervention and the BOP test, in line with the well-control and HSE standard of the operator and the contractor.
Operations report every 24 hours, a decision log, classified non-productive time and a close-out report per well.
Wireline, coiled tubing, cementing and perforating with vetted vendors; technical and sequence coordination handled by our engineering.
Contracts with defined scope, counterparty verification and compliance with the regulations applicable to each project.
The team
Integrated studies, material balance, reserves and candidate screening.
Diagnosis, nodal analysis, artificial lift and well testing.
Workover engineering supervision, fishing, squeeze cementing and well control.
Completion design, perforating and initial evaluation.
Operational programs, risk analysis and change control.
Specification, inspection and logistics of tubulars and materials.
Field experience, not desk experience · 20+ years in Venezuelan fields. A team based in Venezuela, trained in workover, recompletion and completion with operators and joint ventures, in light and medium crude and gas-condensate reservoirs. Nationwide coverage.
Engagement models
Program review and validation, a well engineer on location, and candidate and risk assessment for a client team.
Execution of one or several phases, from the integrated study to the workover program.
Engineering responsibility across the seven phases, through to bringing the well on production and the close-out report, per the program and the handover criteria agreed with the client.
Recommendation: start with phases 1 to 3 on a group of wells. It delivers ranked, diagnosed candidates before committing a rig, and lets the client validate the team on a bounded scope.
Next steps
Technical meeting
Review of the field, the idle-well inventory and the available information (logs, history, diagrams).
Confidentiality agreement and data access
Production and injection history, pressure tests, logs, mechanical diagrams and past interventions.
Phase 1–3 proposal
Scope, schedule, assigned team and committed deliverables for the integrated study, candidate screening and diagnosis.
