Weekly Strategic Review | Issue #004 | 25 September 2026

Bolivia Doesn’t Just Need Investment. It Needs an Industry Capable of Turning Investment into Production.

Much of the discussion surrounding the revitalisation of Bolivia’s hydrocarbons sector understandably focuses on investment.

How can Bolivia attract international capital back into exploration and production? What fiscal terms will investors require? How should the Hydrocarbons Law be reformed? What protections should a new Investment Law provide?

These are important questions.

But developments during the past week point to another, more immediate challenge.

Bolivia must not only attract investment. It must rebuild the petroleum operating system capable of converting that investment into production.

That distinction matters.

A country can possess excellent geology, competitive fiscal terms and willing investors, yet still struggle to increase production if operators are not being paid, service companies are disappearing, experienced personnel are leaving, equipment is idle and contracts take too long to become executable.

The investment problem and the operating-capability problem are therefore inseparable.

Energy pricing is becoming more economically realistic

One of the most significant developments has occurred outside the upstream sector itself.

Under DS 5716, diesel moved to an initial price of Bs 17.95 per litre, linked more closely to import-parity economics rather than the previous fixed subsidised structure.

For upstream investors, the significance goes beyond the price at the pump.

It introduces an important economic principle: Bolivia is beginning to recognise the replacement cost of imported energy.

That has direct implications for domestic hydrocarbon production.

Every additional barrel produced domestically can potentially displace energy that would otherwise have to be imported using scarce foreign currency and transported into the country.

This should make the economic value of incremental domestic production increasingly visible.

But there is another side to the equation.

Higher fuel costs also increase the cost of drilling, workovers, logistics, transportation and field services.

If Bolivia expects its petroleum industry to operate with increasingly international input costs, it will also need to offer upstream economics capable of generating internationally competitive returns.

Downstream pricing reform and upstream fiscal reform are therefore more closely connected than they may initially appear.

Mature fields offer a practical route to early production

YPFB’s intervention programme at the mature Bermejo and Toro fields provides a useful illustration of what a short-cycle production strategy could look like.

YPFB reported that combined production from the two areas increased from approximately 95 barrels per day to around 140 barrels per day, following interventions involving nine wells at Toro and two at Bermejo.

Among them was Bermejo-33, a well that had been closed for years and has now returned to stable production.

At national scale, an additional 45 barrels per day is clearly modest.

But that is not the most important part of the story.

The important point is the sequence:

existing field → existing well → intervention → incremental production

Compare that with frontier exploration:

acreage → seismic → prospect → exploration well → appraisal → development → infrastructure → production

The latter can create enormous value, but it can also require hundreds of millions of dollars and many years before the first commercial production is achieved.

Bolivia needs exploration.

Its declining reserves ultimately make renewed exploration unavoidable.

But while the exploration sector is being rebuilt, mature fields offer something different: the possibility of converting relatively small amounts of capital into production and cash flow comparatively quickly.

Bolivia should build a national inventory of short-cycle opportunities

The Bermejo and Toro results suggest that mature-field rehabilitation should become a systematic programme rather than a collection of isolated interventions.

Bolivia has decades of production history.

Across that legacy asset base there are likely to be opportunities involving:

shut-in wells;
underperforming producers;
bypassed productive intervals;
artificial-lift optimisation;
recompletions;
stimulation;
water-management improvements;
facility debottlenecking; and
selective infill drilling.

Not every opportunity will be economic.

Some old wells were abandoned for very good technical reasons. Others may require more capital than the incremental production can justify.

That is why mature fields should not simply be ranked according to historical production or remaining oil in place.

They should be ranked economically.

For each intervention, the critical questions are relatively straightforward:

How much capital is required?

How quickly can the work be executed?

What incremental production is expected?

How rapidly will that production decline?

What is the expected ultimate incremental recovery?

And how long will it take to recover the investment?

The central KPI should therefore be something close to:

sustainable incremental barrels or cubic feet produced per dollar invested.

That would allow Bolivia to direct scarce capital toward projects capable of generating the fastest economically sustainable production response.

But who will perform the work?

This is where the investment case becomes more complicated.

The Cámara Boliviana de Hidrocarburos y Energía (CBHE) has warned that Bolivia’s oilfield-services ecosystem is under severe financial pressure.

Its public statements have referred to approximately 6,000 specialised personnel leaving the sector, together with exceptionally low utilisation of the country’s drilling fleet.

These are industry-association estimates rather than independently audited national statistics and should be treated accordingly.

But the underlying issue is strategically important.

An upstream petroleum industry consists of much more than reservoirs, acreage and capital.

To rehabilitate a mature field, Bolivia needs pulling units, wireline, cementing, logging, stimulation, well testing, artificial-lift equipment and facilities contractors.

It needs reservoir engineers, production engineers, drilling and completion specialists, supervisors, technicians and experienced field personnel.

It needs equipment that works and companies financially capable of maintaining it.

In other words, oilfield-service capacity is itself petroleum infrastructure.

And once that capability disappears from a country, rebuilding it takes time.

A company that has laid off an experienced crew cannot necessarily recreate that crew next month simply because a new contract has appeared.

Equipment that has left Bolivia may need to be imported again.

Specialists who have moved abroad may not return unless they see a sustainable pipeline of work.

This is why mature-field rehabilitation has a second potential benefit beyond the incremental barrels.

A sustained programme of interventions could create enough activity to keep service companies, equipment and experienced people economically active while Bolivia rebuilds the larger exploration sector.

The US$340 million question

Perhaps the most consequential issue raised during the week concerns operator cash flow.

CBHE has stated that approximately US$340 million in contractual remuneration is outstanding to operating companies, accumulated over close to three years.

The figure should be treated carefully.

It is a CBHE claim and, at the time of writing, has not been matched by a publicly available September 2026 reconciliation from YPFB.

However, the existence of a substantial historical backlog is not new.

Public reporting in 2024, citing a formal Ministry response, placed YPFB’s outstanding operator remuneration at US$248.87 million as of December 2023, covering recoverable costs and operator profit.

The strategic importance of the current claim becomes particularly clear when compared with investment.

YPFB’s 2026 investment programme envisages approximately US$88.26 million from operating companies.

If the CBHE’s current US$340 million figure is broadly correct, the claimed outstanding remuneration would therefore be almost four times operators’ entire programmed investment for 2026.

That comparison goes directly to the question of investor confidence.

Investment protection begins with existing contracts

Bolivia is working on a new Investment Law and comprehensive reform of Hydrocarbons Law 3058.

International investors will certainly examine the resulting fiscal terms, legal protections, dispute-resolution mechanisms and expected returns.

But sophisticated investors will conduct another form of due diligence as well.

They will talk to companies already operating in Bolivia.

And one of the simplest questions they will ask is:

Were you paid according to your contract?

That answer can carry enormous weight in an investment committee.

A government can offer an attractive theoretical internal rate of return on a new project. But if existing operators cannot convert contractual entitlements into predictable cash flow, investors will incorporate that risk into their valuation—or deploy their capital somewhere else.

For that reason, a transparent reconciliation of outstanding operator balances, followed by a credible settlement mechanism and normalisation of current payments, could potentially become one of the most powerful investment-confidence measures available to Bolivia.

Contractual credibility is not separate from investment promotion.

It is one of its foundations.

International interest is improving

There are nevertheless encouraging signs.

President Rodrigo Paz’s 21 September meeting with U.S. Secretary of State Marco Rubio explicitly included international investment on the bilateral agenda.

This comes as Bolivia seeks to restore international investor confidence and attract capital into strategic sectors, including energy.

But diplomatic interest and investment discussions remain several stages removed from an executable petroleum project.

As of the end of the week, several important legislative and contractual initiatives remained under treatment in the Chamber of Deputies, including:

PL 684 — Investment Law

PL 756 — comprehensive reform of Law 3058

PL 343 — Okinawa petroleum-services contract

PL 342 — Vintage Petroleum contract addendum

This produces an important distinction.

International interest may be improving, but legislative and contractual conversion remains incomplete.

Ultimately, investors cannot drill political interest.

They drill contracts.

Could Bolivia absorb US$500 million tomorrow?

There is a useful thought experiment.

Suppose an international investor arrived tomorrow and committed US$500 million to Bolivia’s upstream petroleum sector.

What would have to happen before those dollars became additional oil or gas production?

Bolivia would still need technically ranked opportunities.

It would need commercial agreements.

It would need executable contracts.

It would need regulatory and environmental approvals.

It would need operators with predictable cash flow.

It would need rigs and service companies.

It would need engineers, technicians and supervisors.

It would need roads, facilities, pipelines and other infrastructure.

And it would need an approval system capable of operating on commercial timescales.

This illustrates the difference between attracting investment capital and possessing the capacity to absorb investment capital productively.

They are not the same problem.

And solving only the first will not automatically solve the second.

A possible sequence for rebuilding the industry

The developments of recent weeks suggest that Bolivia’s hydrocarbons recovery could benefit from a deliberate sequence.

First, restore contractual credibility.

Reconcile outstanding operator balances transparently, establish how they will be settled and ensure that current contractual obligations are subsequently paid normally.

Second, preserve operating capability.

Keep specialised contractors, equipment and petroleum professionals economically active before more of that capability leaves the country.

Third, scale short-cycle production.

Create a technically and economically ranked national portfolio of mature-field interventions, shut-in wells, recompletions, artificial-lift opportunities and other relatively rapid production projects.

Fourth, complete the legal and investment framework.

Make fiscal terms, investment protection, contract approval and regulatory processes competitive and predictable.

Fifth, scale larger capital deployment.

With the operating foundations strengthened, Bolivia will be better positioned to pursue larger conventional exploration programmes, low-permeability developments and significant foreign investment.

These activities do not need to occur completely sequentially; much of the work can and should proceed simultaneously.

But the logic of the sequence matters.

There is limited value in attracting billions of dollars if the system subsequently requires years to convert those dollars into wells and production.

Conversely, there could be considerable value in demonstrating that relatively small investments can already be converted efficiently into incremental barrels and cubic feet.

Measure production, not announcements

This suggests another change in how the recovery of Bolivia’s hydrocarbons industry might be measured.

Investment announcements are useful.

New laws are important.

Meetings with potential investors matter.

But ultimately none of them produces hydrocarbons.

A more revealing scorecard would track operational metrics such as:

Days from commercial agreement to executable contract

How quickly can an agreed investment opportunity become legally executable?

Capital invested per unit of incremental production

How efficiently are dollars being converted into sustainable barrels or cubic feet?

Percentage of contractual operator remuneration paid on schedule

Is the commercial system functioning predictably?

Active rigs and service capacity versus planned activity

Does Bolivia actually possess the operational capability required to execute its investment programme?

Over time, these measures would reveal whether reform is becoming an operating petroleum industry rather than remaining a collection of policy initiatives.

Rebuilding the petroleum operating system

Bolivia unquestionably needs capital.

It needs renewed exploration, reserve replacement, technology, international expertise and substantially greater upstream investment.

But capital is only one component of the recovery.

The developments of the past week highlight five interconnected requirements:

Economic realism. Domestic production must be valued against the real cost of imported replacement energy.

Early production. Mature-field interventions can potentially generate barrels and cash flow comparatively quickly.

Operating capacity. Bolivia must preserve or rebuild the companies, equipment and people capable of executing those projects.

Contractual discipline. Operators need predictable payment if they are expected to reinvest.

Investable law. Hydrocarbon and investment legislation must convert investor interest into bankable, executable projects.

Remove any one of these elements and the chain becomes weaker.

That may be the most important lesson from a week in which Bolivia announced no major discovery, reserve addition or foreign farm-in.

The investment case nevertheless changed.

The challenge is becoming clearer.

Bolivia does not simply need to attract more money into hydrocarbons.

It needs to rebuild an industry capable of turning that money into sustainable production.

Bolivia Hydrocarbons Intelligence is an independent intelligence and analysis publication from Colin Dunlop Consulting, focused on the developments shaping Bolivia’s hydrocarbons sector, investment environment and upstream opportunities.

Colin Dunlop | Petroleum Engineer & Project Manager | Santa Cruz, Bolivia

Bolivia Hydrocarbons Intelligence — 25 September 2026