Colombia’s Second Discovery

GLIAG | STRATEGIC UPSTREAM INTELLIGENCE

COLOMBIA’S SECOND DISCOVERY

The State Capacity to Convert Geology into Sovereignty — From President De La Espriella’s Policy Reset to a Bankable 2027-2035 Upstream System

A Socratic, Independent GLIAG Petroleum Strategy Essay

Marcel P.T. Chin-A-Lien, Drs., MBA, M.Sc., Ing. Geologist
Principal Founding Partner & Chief Architect, GLIAG
5 September 2026 | GLIAG-FLAGSHIP-2026-COL-001 | Rev 02

ROOTED IN SURINAME. SMALL BY DESIGN. INDEPENDENT BY METHOD.

Executive verdict

GLIAG VERDICT Colombia does not primarily suffer from a shortage of geological possibility. It suffers from a conversion gap: too few prospects become wells, too few discoveries become reserves, too few reserves become deliverable molecules, and too slowly. A policy reset can reopen the gate; only sustained execution can rebuild the supply system.

Colombia’s policy reset identifies the correct direction, but policy alone will not reverse production decline. More committed wells, stronger recovery from mature fields and faster commercialization of Caribbean offshore gas are the right tests. The proposition becomes decision-grade only when it is decomposed by basin, decline mechanism, reserve class, infrastructure, market and timing.

The immediate challenge is stark. Colombia closed 2025 with 2,020 million barrels of proved oil reserves and a 7.4-year oil R/P ratio; proved gas reserves were 1,717 Bcf with a 5.9-year R/P ratio. The country replaced roughly 94 barrels for every 100 barrels produced in 2025. That is stabilization, not renewal. Gas is more urgent: the proved base implies annual production near 291 Bcf, or roughly 0.80 Bcfd, while planners model LNG as a structural bridge and Sirius as a contingent post-2030 supply pillar.

GLIAG’s central conclusion is therefore a two-clock strategy. Clock One, 2027-2030: defend base production with disciplined infill, workovers, waterflood optimization, EOR/PPI and rapid tie-ins of onshore gas. Clock Two, 2030-2035: convert Sirius and its satellites into a bankable offshore hub, restore a repeatable exploration inventory and selectively test unconventional resources under scientifically credible regulation and social consent. Failure on either clock creates imports, fiscal erosion and loss of service-sector capability.

FLAGSHIP PROPOSITION Colombia’s first discovery was geological: prolific basins, mature fields and a Caribbean gas province. Its second discovery must be institutional: the capacity to turn evidence into permits, permits into wells, wells into facilities, facilities into contracts and contracts into durable national value.

The numbers that matter

Indicator	Verified position	GLIAG interpretation
Oil 1P, YE2025	2,020 MMbbl; R/P 7.4 years	Short reserve life; annual replacement must exceed production to rebuild resilience
Gas 1P, YE2025	1,717 Bcf; R/P 5.9 years	Near-term security problem; offshore 2C is not yet supply
2025 oil additions	257 MMbbl; 94% replacement ratio	Good operational recovery, insufficient for durable growth
EOR/PPI contribution, 2018-2025	436 MMbbl; 22% of additions	Material value lever, but bounded by remaining mobile oil and project economics
Gas contingent resources	10.54 Tcf in 3C	Large option set, high uncertainty; do not equate 3C with reserves
Sirius concept	~6 Tcf gas in place; ~460-470 MMcfd concept	Potential anchor; FID, recoverability, license, consultation and pipeline remain gates
Ecopetrol 2026 plan	730-740 kboe/d; 380-430 development wells; 8-10 exploration wells	Development-heavy program protects plateau but may not rebuild exploration depth

1. The first analytical discipline: separate policy from supply

What the evidence establishes

The sequence matters: rebuild drilling, defend existing production, establish the next supply base.
Acreage and policy announcements are leading indicators, not barrels.
Near-field drilling and enhanced recovery can soften decline before 2030.
Post-2030 gas security hinges disproportionately on Sirius and on whether onshore discoveries become repeatable commercial developments.
Investor confidence must be observed through committed capital, wells and project sanctions, not conference rhetoric.

What national framing can still conceal

First, ‘production decline’ is not one mechanism. It is the net result of reservoir depletion, rising water cut, facility uptime, pipeline constraints, security interruptions, deferred workovers, exploration drought and capital allocation. Each requires a different remedy. Second, a national supply-demand view can hide quality and location: heavy Llanos crude, Middle Magdalena barrels, Caribbean dry gas and deepwater offshore gas are not interchangeable units. Third, any national development thesis remains incomplete until the commercial assumptions behind Sirius timing, LNG utilization, pipeline tariffs and reserve maturation are explicit.

Decision models should retain native units and state every conversion factor. GLIAG therefore separates liquids, sales gas and boe-equivalent views and does not allow a visually convenient unit to obscure the molecule balance.

SOCRATIC QUESTION If the policy changes tomorrow, which already-mapped prospects can be permitted, financed and drilled early enough to affect 2030 production? If that list is not named, ranked and scheduled, the policy reset remains political optionality rather than supply.

2. The President’s proposition: strength before transition

President Abelardo De La Espriella has given Colombia’s energy debate a new organizing sentence: the transition should be built from strength and self-sufficiency rather than weakness and dependence. In his inaugural address he promised wider oil and gas exploration, ‘responsible and sustainable fracking,’ a stronger Ecopetrol and a government that acts as an investment partner. The proposition is economically intelligible: a country importing an increasing share of its gas while holding short proved reserve life is not made cleaner or more sovereign merely by refusing to replenish supply.

Yet political direction must be separated from executable policy. The president can change tone, priorities, appointments and some administrative processes quickly. He cannot by rhetoric alone settle fiscal durability, consultation rights, environmental licensing, Congressional opposition, security, community benefit-sharing or the economics of marginal barrels. Reuters reported 120 prior consultations still associated with Sirius, a 34% decline in foreign mining-and-oil investment between 2023 and 2025, and 580 attacks or blockades on infrastructure in 2025. These are not footnotes to the supply model; they are variables inside it.

A constructive, non-partisan test of the new doctrine

Presidential commitment	What would validate it	What would falsify it
Reopen exploration	Competitive terms, data access, committed wells and diverse qualified bidders	Acreage announcements without executable work programs
Strengthen Ecopetrol	Transparent portfolio hurdles, partner leverage, reliable operations and reserve renewal	Using the company simultaneously as fiscal reservoir and policy vehicle
Responsible fracking	Limited scientific pilots with baseline water/seismic data, disclosure and independent monitoring	National production forecasts before repeatable pilot economics and social legitimacy
Accelerate permitting	Parallel processing, early consultation and published critical paths that preserve substantive rights	Shortcuts that trigger injunctions, delay and loss of legitimacy
Attract investment	Stable after-tax returns, security, enforceability and credible project queues	Short-lived incentives vulnerable to the next administration

GLIAG JUDGMENT The new policy improves option value immediately; it improves reserves only after commercial discoveries are booked, and it improves supply only after safe first sales. Markets should reward evidence at each gate, not capitalize the entire political promise on day one.

3. Colombia’s upstream system is a portfolio of different geologies

Colombia’s petroleum endowment is fragmented across intermontane forelands, fold belts, strike-slip basins and offshore accretionary/deformed margins. National averages conceal different charge systems, reservoir architectures, decline profiles and surface constraints. Strategy must therefore be basin-specific.

Basin / fairway	Geological engine	2027-2035 role	Primary risk
Llanos	Andean foreland; Cretaceous-Paleogene reservoirs charged from deeper western kitchens; structural/stratigraphic traps	Largest near-term oil-defense engine: infill, waterflood, facilities and near-field exploration	Mature decline, water handling, differential access/security and heavy-oil economics
Middle Magdalena Valley	Inverted rift/intermontane basin; prolific La Luna source, complex structures, stacked reservoirs	Brownfield recovery, redevelopment, selective deeper or bypassed-pay targets	Old infrastructure, compartmentalization, environmental and community constraints
Putumayo	Northern Oriente continuation; Cretaceous clastics, structural traps and underexplored stratigraphy	Selective exploration and tie-back oil; regional Ecuador portfolio logic	Security, logistics, permitting and smaller fragmented developments
Catatumbo	Maracaibo-related petroleum system with Cretaceous source/reservoir elements	Selective rehabilitation and exploration optionality	Security and cross-border complexity
Sinú-San Jacinto / Lower Magdalena	Thrusted fold belt and clastic gas systems; Ciénaga de Oro and deeper intervals	Fastest material onshore gas-growth candidate if Hechicero-style results repeat	Well deliverability, reservoir continuity, commercialization and pipeline capacity
Guajira offshore / GUA-OFF-0	Biogenic and thermogenic gas systems; deepwater turbidites and structural-stratigraphic traps	Sirius-led national gas hub with Copoazú and Sandía satellites	Appraisal, social/environmental license, 117-km evacuation and capex
Southern Caribbean Deformed Belt	Deepwater thrusts, mass-transport systems and multiple gas discoveries	Second offshore option set; long-dated strategic diversification	Ultra-deepwater cost, reservoir quality, market timing and stranded-resource risk
Middle Magdalena unconventional	La Luna and related source-rock potential	Post-2030 option only after pilots prove repeatability and safeguards	Social license, water, induced seismicity, regulation, cost and political reversal

The geological priority is not ‘more acreage’ but better conversion

The most valuable new acreage is acreage adjacent to proven charge, infrastructure and operating capability. In mature basins, the highest-value technical work may be reprocessing, static/dynamic model integration, recompletion candidates, unswept compartments and facility debottlenecking. In frontier offshore acreage, the priority is cluster scale: a moderate satellite can be more valuable beside Sirius than a larger isolated discovery without an evacuation route.

This is why GLIAG rejects a false choice between mature fields and frontier exploration. Mature fields buy time; frontier hubs buy the future. The portfolio must fund both, with different hurdle rates, risk budgets and performance metrics.

4. Oil: defend the base without mistaking recovery for renewal

What the 94% replacement ratio really says

ANH reports 257 MMbbl of proved additions in 2025 and a 94% replacement ratio. Algebra implies production near 273 MMbbl for the year, or about 0.75 million b/d. The result is respectable after years of limited new contracting, but below the threshold needed to expand reserve life. A sustainable rebuilding phase requires a multi-year replacement ratio above 100%, ideally with a growing share from new discoveries and commerciality maturation rather than revisions alone.

EOR is a national asset-management program

Between 2018 and 2025, EOR and production-increment projects added 436 MMbbl, 22% of all reserve additions. That validates enhanced recovery as a strategic pillar. It does not justify indiscriminate EOR. Each candidate needs reservoir-specific screening: remaining oil saturation, mobility ratio, heterogeneity, pressure support, injectant availability, produced-water capacity, polymer or chemical compatibility, incremental emissions and full-cycle economics.

Mature-field lever	Best use	Decision metric	Failure mode
Infill / sidetrack	Known compartments with calibrated connectivity	Incremental EUR per well; payout; interference	Cannibalization and accelerated decline
Waterflood optimization	Pressure maintenance and sweep improvement	Pattern balance, VRR, water cut, sweep efficiency	Moving water rather than oil
Polymer / chemical EOR	Adverse mobility and material remaining oil	Incremental recovery vs chemical and handling cost	Injectivity loss, breakthrough, supply chain
Recompletion / behind-pipe pay	Stacked or bypassed intervals	Low-capex incremental production and reserves	Poor isolation or weak reservoir quality
Facilities debottlenecking	Oil constrained by water, power, compression or export	Deferred production recovered per dollar	Reservoir decline mistaken for surface constraint
Digital surveillance	Large mature asset portfolios	Faster anomaly detection, allocation accuracy, workover ranking	Data without operational authority

Why 1.3 million b/d is not yet a plan

The new administration has been associated with an ambition to approach 1.3 million b/d. Against a recent national base near three-quarters of a million barrels per day, that implies roughly 0.55 million b/d of net uplift before offsetting natural decline. Without field-by-field sources, well counts, facility capacity, decline curves, capex and a timetable, the number is a political aspiration. A credible plan should first define a defendable 2030 band, then show how each project fills the decline wedge.

5. Gas: Colombia’s more urgent and strategically richer problem

Gas has only 5.9 years of proved reserve life, and its geography matters because demand, pipelines and hydro-dependent power reliability are spatially constrained. LNG imports are no longer a temporary embarrassment; they are a rational insurance instrument while domestic projects mature. The mistake would be to overbuild rigid import capacity that becomes stranded when Sirius arrives—or to underbuild and expose power and industry if Sirius slips.

Onshore bridge: Sinú-9 and rapid molecules

Maurel & Prom’s Hechicero-1X result is commercially important because it combines 288 ft of reported net gas pay with an instantaneous 26.4 MMcfd test at 1,800 psi wellhead pressure through a restricted choke, and it can use existing connections to the national network. One test is not a plateau. GLIAG would require stabilized rates, pressure-transient analysis, composition, deliverability decline, interference and repeatability across the six-well campaign. If repeated, Sinú-9 can become a genuine 2027-2030 bridge rather than a single-well headline.

Offshore structural solution: Sirius as a hub, not a solitary field

The Sirius complex—together with Copoazú and Sandía—should be evaluated as one pressure-fluid-seismic-development system. The public concept of approximately 460-470 MMcfd through a roughly 117-km subsea-to-shore pipeline can transform the national balance, but gross gas in place is not sales gas. Recovery factor, CO2 and inert content, condensate yield, compression, uptime, domestic contracts, tariff design and consultation determine bankability.

GLIAG DEVELOPMENT DOCTRINE Do not freeze the Sirius facilities concept before cluster-wide appraisal. Design modular compression, control and pipeline capacity so satellites can extend plateau or fill ullage. The unit of value is the hub, not the discovery press release.

The import paradox

UPME’s 2025-2055 planning framework explicitly treats Sirius 2C as an exogenous assumption in announced-policy and carbon-neutrality scenarios, with entry from 2031, while preserving LNG expansion options. That is prudent planning, but it also reveals systemic dependence on a single contingent project. Colombia should contract import flexibility—shorter tenure, seasonal rights, capacity release and modular regasification—rather than assume either permanent LNG dependence or flawless offshore delivery.

6. Policy reset: what must actually change

A new administration can signal openness immediately, but several material measures require law, regulation, institutional coordination or Congressional approval. Reuters reports that simplified permitting may be pursued by decree, while royalty changes, contract redesign, tax incentives and fracking parameters face a divided Congress. The durable reset is therefore an execution compact, not an ideological reversal.

Publish a prospect-to-first-production inventory, with named gates, responsible institutions and dates.
Separate fast-track brownfield and tie-in projects from frontier licensing; do not subject both to one process clock.
Create a predictable consultation protocol that begins before concept selection and preserves substantive rights.
Stabilize fiscal and contract terms across the investment cycle, with transparent grandfathering and dispute resolution.
Use bid design to reward data acquisition, well commitment and infrastructure sharing—not signature bonuses alone.
Make methane, water, flaring and abandonment performance measurable conditions of continued license quality.
Protect Ecopetrol from becoming either a cash machine for the state or a vehicle for politically selected megaprojects.

7. Ecopetrol: anchor, allocator and potential bottleneck

Ecopetrol is simultaneously national champion, major producer, refiner, transporter, offshore partner and transition investor. This breadth creates integration value but also capital-allocation conflict. Its 2026 plan directs about 70% of investment toward production, with 380-430 development wells and only 8-10 exploration wells. That can defend near-term output, but exploration depth may remain thin unless partners carry more frontier risk.

The correct governance question is not whether Ecopetrol should be ‘restored’ in political terms. It is whether each capital tranche earns its strategic mandate. Brownfield cash generation, Sirius infrastructure, exploration, refining reliability, power and low-carbon investments should each have explicit return, resilience and emissions criteria. Sovereign objectives must be priced rather than hidden inside corporate performance.

8. The 2027-2035 practical program

Phase	Operational agenda	Observable proof	GIP trigger
2027-2028: Stabilize	Commit development and near-field wells; accelerate workovers/EOR; tie in onshore gas; complete Sirius appraisal/licensing architecture	Rig and well count rises; base decline moderates; stabilized Sinú deliverability; consultation milestones	Monthly well funnel, field uptime, reserve movements, gas contracts
2028-2030: Convert	Sanction Sirius hub/pipeline; award selective high-quality exploration; lock flexible LNG bridge; debottleneck mature assets	FID, EPC and financing; pipeline progress; multi-year reserve replacement >100%	Capex-at-risk, schedule confidence, contracted demand, permitting critical path
2030-2032: Deliver	First Sirius gas or transparent rebaseline; satellite tie-back decisions; scale repeatable onshore gas; begin new discovery maturation	Sales gas, uptime and plateau; LNG displacement; new 2P/1P bookings	Supply-demand balance by node, hub ullage, tariff and import utilization
2032-2035: Renew	Second offshore node or satellites; sustained frontier drilling; selective unconventional pilots only if validated	New supply base offsets mature decline; reserve life rises; pilots meet environmental and cost thresholds	Portfolio NPV, emissions intensity, reserve life, social-performance score

A realistic scenario envelope

Scenario	2030 condition	2035 consequence	GLIAG probability posture
Execution reset	Policy becomes contracts, wells, EOR and Sirius FID	Oil broadly stabilized; gas deficit narrowed or reversed; hub optionality	Plausible, but requires cross-government delivery
Announcement reset	Licensing rhetoric rises; permitting, Congress and project gates remain slow	Temporary investment interest; production resumes decline; LNG dependence grows	Material downside risk
Brownfield-only success	EOR and development wells outperform; frontier conversion lags	Oil decline softened; reserve life remains short; gas structurally tight	Useful bridge, not renewal
Offshore delay	Sirius slips beyond 2031/32 or costs rise materially	Higher LNG utilization and prices; stranded/underused infrastructure risk	Must be explicitly hedged
Full portfolio renewal	Mature fields, onshore gas, Sirius cluster and exploration all convert	Colombia re-emerges as investable Northern Andes platform	Upside; should not be base case before observable gates

9. Regional strategy: Colombia is becoming a Northern Andes operating platform

Colombia’s service companies are already moving into Venezuela, while GeoPark and Grupo Gilinski have signed a 25-year agreement around the Bare field and KEO Energy has reportedly taken operational and cash-flow management responsibility in PetroUrdaneta with up to US$350 million of financing. Chevron’s reported multi-year Venezuelan expansion adds another demand center for drilling, workovers, power and logistics. These are not separate news items. They suggest a regional service and operating corridor in which Colombian capability can export west-to-east while Venezuelan opportunities diversify Colombian corporate portfolios.

The opportunity carries asymmetric risk. Venezuela may create rapid brownfield work, but sanctions, title, payment, governance and contract durability must remain ring-fenced. Colombia should not allow domestic drilling capacity to be pulled across the border before its own reserve-replacement program is rebuilt. For companies, Venezuelan upside belongs in a licensed option bucket; Colombian producing cash flow and infrastructure should remain the base.

For Guyana, Suriname and Trinidad, Colombia’s offshore gas matters because capital, subsea suppliers and LNG/import economics are regional. A sanctioned Sirius hub competes for deepwater engineering capacity, but it also validates a larger Atlantic-Caribbean gas-services market. Trinidad remains the monetization benchmark; Guyana and Suriname remain liquids-led basin comparators; Venezuela remains the highest-resource, highest-institutional-risk comparator.

10. GIP integration architecture

GLIAG plans to incorporate dedicated dashboard architectures for the Guyana–Suriname Basin (GSB), Venezuela and Colombia into the GIP. Each is intended to connect basin and subsurface evidence with wells, infrastructure, commerciality, policy, sovereign risk and investor decision gates. These are planned capabilities: until implementation is complete, the present essay should be read as an independent analytical blueprint—not as a claim that the full dashboard functionality is already operational.

GIP layer	Required fields	Decision use
Basin & petroleum system	Sources, reservoirs, play type, maturity, charge, trap, seal, discovery analogues	Rank where geology can support repeatable conversion
Field decline & recovery	Production, decline, water cut, uptime, injection, remaining reserves, EOR stage	Separate reservoir decline from surface constraints
Well funnel	Prospect, permit, spud, result, completion, tie-in, first sales	Measure policy-to-barrel conversion time
Gas balance	Native MMcfd by field/node; firm demand; transport; LNG; contracted vs interruptible	Avoid boe conversions obscuring regional bottlenecks
Sirius hub	Resources by class, appraisal, license, consultation, FEED/FID, capex, pipeline, tariffs	Calculate schedule confidence and import displacement
Fiscal & political	Royalty, tax, contract form, consultation, litigation, security, government actions	Price policy durability and sovereign risk
Capital & economics	Brent/HH/LNG assumptions, capex, opex, decline, NPV, IRR, payout, emissions cost	Compare brownfield, onshore gas, offshore and unconventional options
Regional operators	Ecopetrol, Petrobras, Shell, M&P, GeoPark, Parex and relevant partners	Track operating control, balance sheet and cross-border optionality

Mandatory confidence language

Verified fact: primary regulator/company disclosure or audited filing.
Reported claim: credible reporting, not yet evidenced by underlying document.
GLIAG inference: reasoned conclusion from named evidence.
Scenario: conditional future state with explicit trigger and falsifier.
Unverified: do not encode as a canonical GIP value.

11. Why GLIAG’s integrated method changes the answer

This essay applies one integrated evidence chain: GIP’s basin and asset architecture, GLIAG’s petroleum-system work, field and decline logic, company disclosures, official reserve and planning data, policy and legal evidence, regional geopolitics, and the daily signal discipline of Global Basin Watch. The purpose is to make each conclusion traceable from geological possibility through execution to economic and sovereign consequence.

That integration creates a practical edge. A geologist sees charge, reservoir, seal and trap. A reservoir engineer sees decline, sweep and deliverability. A project financier sees sanctioned volumes, tariffs and debt capacity. A policymaker sees reserve life, imports, revenues and social legitimacy. An investor sees timing, optionality and downside. GIP places these views in one evidence chain so that no discipline can quietly export its uncertainty to another.

GLIAG intelligence layer	Analytical contribution	Decision output
GLIAG deep research	Independent triangulation of primary, scientific, corporate and political evidence	A defensible thesis with explicit uncertainty
GIP platform	Living basin, asset, well, infrastructure, fiscal and risk architecture	Traceable country-to-prospect and prospect-to-cash decisions
GBW–South America	Daily detection of policy, operator, service, financing and cross-border signals	Early-warning changes to the Colombia/Venezuela investment case
GBW–GSB	Comparative learning from Guyana, Suriname, Trinidad and the wider Atlantic margin	Better hub, gas-to-shore and sovereign-conversion choices
GLIAG Socratic protocol	For every claim: What is known? What is assumed? What must happen next? What would prove us wrong?	Reduced narrative risk and clearer investment gates

Integrated by design, independent by method

GLIAG works through architecture, independence and consequence. The method connects subsurface possibility to above-ground executability and then asks whether the result creates durable value for operators, investors, governments and communities. This is the meaning of ‘Where Information Becomes Intelligence’ and of the more demanding promise: ‘Most people report transactions. GLIAG interprets consequences.’

GLIAG METHOD GLIAG codifies nearly five decades of geological, commercial and sovereign advisory experience into an integrated intelligence architecture usable from a desk, an iPad or a phone—while keeping uncertainty visible, evidence traceable and decisions conditional on observable gates.

12. Newsletter integration

GBW-South America lead signal

SUGGESTED HEADLINE Colombia’s Policy Reset Opens the Gate—but Only Wells, Recovery and Sirius Can Rebuild Supply

The 2026 policy reversal is material because it can restore exploration contracting and investor confidence after four years of stagnation. It does not yet change the production base. The next evidence is a committed 2027-2030 well inventory, repeatable mature-field reserve additions, stabilized onshore gas deliverability and a financeable Sirius development schedule. Until then, treat the reset as improving option value, not proved supply.

GBW-GSB comparative sidebar

Colombia offers Suriname and Guyana a warning and a lesson. Discoveries can remain stranded when permitting, consultation, pipeline and market architecture lag. Conversely, mature-field optimization can fund frontier development if national-company capital allocation is disciplined. The GSB should build domestic gas routing, consultation and commercialization pathways before resource announcements outrun infrastructure.

Venezuela cross-feed from the supplied screenshots

KEO/PetroUrdaneta: verify executed contract, fields, financing draw conditions, operator authority, production baseline and cash waterfall before treating US$350 million as committed capital.
Chevron: treat US$7 billion and 600 kboe/d as promotional/forward-looking claims pending Chevron filings, license terms, field-level capex and production schedules.
Venezuela Energy Week 2027 is a market-sentiment and network signal, not evidence of capital deployment.
Colombian service-company entry and the GeoPark/Gilinski Bare agreement are stronger execution signals, but remain exposed to Venezuela-specific payment, sanctions and enforceability risk.

13. The investment-committee test

Before allocating capital to Colombia, an investor should demand answers to ten questions:

Which fields offset the modeled natural decline through 2030, and at what capex per incremental barrel?
How much 2025 reserve addition came from revisions, extensions, improved recovery and discoveries?
Which exploration wells can realistically reach first production before 2032?
Which assets are reservoir-constrained, facility-constrained, security-constrained or permit-constrained?
What domestic gas price and take-or-pay structure makes Sirius bankable while protecting consumers?
How much LNG capacity remains economic if Sirius arrives on time; what if it slips three years?
Does Ecopetrol have balance-sheet room for upstream, refining, transmission and transition commitments simultaneously?
Can consultation and environmental review be accelerated without weakening legitimacy and creating litigation risk?
Which unconventional pilots would prove commercial repeatability, water integrity, emissions and induced-seismicity control?
What policy provisions survive the next electoral cycle?

14. Final GLIAG position

Colombia’s 2026 policy reset matters. It removes a self-imposed constraint at the moment reserve life is short and gas imports are becoming structural. But the country will not drill its way out of decline by decree, nor recover its way into a new province through EOR alone.

The most resilient strategy is sequenced portfolio conversion. Use mature-field recovery and development drilling to defend cash flow. Convert fast onshore gas into the 2027-2030 bridge. Sanction Sirius as an expandable cluster hub rather than a stand-alone trophy. Rebuild exploration around basin-specific petroleum systems and infrastructure adjacency. Treat unconventional resources as a scientific pilot program, not a political production forecast. Keep LNG flexible. Protect Ecopetrol’s capital discipline. Measure every policy by the time it takes to become a safe, flowing, saleable barrel or molecule.

THE CONCLUSION Colombia’s future will not be decided by whether it chooses hydrocarbons or transition. It will be decided by whether it can govern depletion, investment, infrastructure and social legitimacy at the same time. Geology supplies possibility. Institutions schedule it. Wells test it. Markets pay for it. Only execution converts it into sovereignty.

LinkedIn launch copy

PUBLICATION PITCH Colombia’s new upstream policy resets the direction—but not yet the supply. GLIAG’s new flagship essay follows the complete chain from petroleum systems and mature-field decline to wells, Sirius, Sinú-9, LNG, consultation, Ecopetrol capital and national value. It applies integrated GLIAG research, the developing GIP intelligence architecture and Global Basin Watch to produce a testable 2027-2035 execution thesis. Read: petroleumenergyinsights.com

#GLIAG #GIP #GlobalBasinWatch #Colombia #Ecopetrol #EnergySecurity #Exploration #Upstream #NaturalGas #Sirius #Sinu9 #PetroleumGeology #EnergyInvestment #LatinAmerica #StrategicIntelligence

References and evidence register

Method, limitations and legal notice

This essay triangulates official Colombian reserve and planning data, company disclosures, peer-reviewed petroleum-system literature, credible reporting and prior GLIAG work. Reserve classes are not interchanged: 1P, 2P, contingent resources and gas in place are treated separately. Forward production, price, capex and timing statements are scenarios unless formally sanctioned and supported by disclosed assumptions.

The following disclaimer, non-reliance notice and intellectual-property terms apply to the essay, its GLIAGoGRAPH, tables, analytical architecture, website edition and any extract or reproduction.

LEGAL, NON-RELIANCE AND INTELLECTUAL-PROPERTY NOTICE

Independent analysis; no professional advice

This publication expresses the author’s independent professional analysis and judgment based primarily on publicly available information. It is provided solely for general strategic, educational and discussion purposes. It is not, and must not be treated as, investment research or a recommendation, solicitation, offer, reserves certification, valuation opinion, fairness opinion, prospectus, engineering design, geological assurance, environmental assessment, legal advice, tax advice, accounting advice, sanctions advice or any other regulated or professional service. Nothing in it creates an adviser-client, fiduciary, contractual, partnership, employment or agency relationship.

Data, reserves, resources and forward-looking statements

Figures, maps, reserve and resource classifications, production rates, decline assumptions, costs, prices, schedules, capacities, project concepts and policy statements may be incomplete, provisional, differently defined, subsequently revised or withdrawn. Oil and gas in place, prospective resources, contingent resources, 2P reserves and proved (1P) reserves are not interchangeable. Scenarios, probabilities, forecasts, inferences and forward-looking statements are conditional analytical constructs, not promises or statements of fact. Actual outcomes may differ materially because of geology, reservoir performance, drilling results, technology, financing, costs, commodity prices, markets, infrastructure, permitting, consultation, environmental requirements, litigation, security, sanctions, political decisions, contract enforceability, force majeure and other risks.

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Copyright © 2026 Marcel P.T. Chin-A-Lien / GLIAG. All rights reserved. The original text, selection and arrangement of evidence, analytical synthesis, taxonomies, tables, graphics, GLIAGoGRAPH, scenario logic, doctrine mapping, confidence language, GIP architecture and expressive structure are proprietary and may also be protected by database rights, confidentiality, contract and other laws. Access, purchase, invitation, transmission or public availability does not transfer ownership, grant a licence or constitute abandonment of rights. Except for brief quotations permitted by law with accurate attribution to Marcel P.T. Chin-A-Lien and GLIAG, no part may be reproduced, copied, adapted, translated, extracted, republished, redistributed, transmitted, sold, sublicensed, displayed, mirrored, re-hosted, incorporated into a database, research product, platform or competing advisory product, or used commercially without prior written authorization.

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Colombia’s Upstream Energy Strategy for 2027-2035