Axip Energy Services - Chapter 11 Case Summary

Business Description

Headquartered in Houston, TX, Axip Energy Services, LP ("Axip"), a Texas limited partnership, together with its Debtor and non-Debtor affiliates (collectively, the "Company"), is a leading provider of natural gas compression services to upstream and midstream customers across major natural gas producing basins in the United States and offshore in the Gulf of Mexico, with a primary focus on the Permian Basin.

• The Company operates a network of seven facilities across Texas, New Mexico, and North Dakota, servicing customers in seven states and offshore regions.
• Through its facility network, the Company deploys approximately 940 compression units generating a total of approximately 326,070 horsepower ("HP"), providing customers with gas lift and gathering compression services.

The Company's gas compression services help customers maximize natural gas and crude oil production and throughput. Specifically, the Company provides two core service lines:

• Gathering Compression: Compression equipment that mechanically increases pressure for more efficient natural gas transportation.
• Gas Lift: Natural gas is injected into a well's production stream to artificially lift fluids, assisting with crude oil production.

Compression services are provided on a fixed-fee initial contract basis or, after the expiration of the initial term, on a month-to-month arrangement. The Company also contracts out a fleet of more than 120 skid-mounted, auxiliary natural-gas coolers, which assist customers with cooling higher-pressure natural gas produced from deeper wells.

The Company maintains an active and diverse customer base of more than 55 companies, including very large, integrated multinational oil and gas companies and other investment-grade producers. The Company serves its customers across the most prolific basins in the United States, with a specific focus on the West Texas Permian Basin and other low-breakeven unconventional shale plays.

As of February 22, 2026 (the "Petition Date"), the Company is privately held and employs approximately 149 full-time and part-time employees, many of whom possess specialized industry and technical knowledge and maintain longstanding relationships with the Company.

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Corporate History

The Company was founded as Valerus Compression Services LP ("Valerus") in 2002. Following various spin-offs and with a renewed focus on its core compression services business line, Valerus changed its name to Axip Energy Services, LP in 2014.

• In September 2022, a fund affiliated with Energy Spectrum Capital LP ("Energy Spectrum") acquired the Company via an equity purchase transaction. Energy Spectrum remains the ultimate majority owner of the Company.

Organizational Structure

The Company's organizational structure consists of 12 entities, seven of which are Debtors in these Chapter 11 Cases.

• E3 Compression Holdings LLC ("E3 Holdings"): A Delaware limited liability company serving as the immediate parent company of Axip Management. E3 Holdings is a holding company whose primary assets consist of its direct and indirect ownership of the equity interests of the other Debtors and the non-Debtor affiliates. E3 Holdings owns 100% of the limited partnership interests in Axip and 100% of the membership interests in Axip Management (defined below). E3 Holdings is a guarantor under the Prepetition Superpriority Credit Agreement and the Prepetition ABL Credit Agreement and is a grantor of a security interest under the Prepetition 2L Loan Documents.
• Axip Energy Services Management, LLC ("Axip Management"): A Texas limited liability company that owns 100% of the general partnership interests of Axip. Axip Management has no material investments or ownership interests other than its direct ownership of the general partnership interests of Axip. Axip Management is a guarantor under the Prepetition Credit Agreements.
• Axip Energy Services, LP: The Company's primary operating entity and the direct owner of 100% of the equity interests of Axip Producer Services, LLC ("Axip Services"), Axip Holdings, LLC ("Axip Holdings"), and Axip Leasing Company, LLC ("Axip Leasing"). Axip is the borrower under each of the Prepetition Superpriority Credit Agreement, Prepetition ABL Credit Agreement, and the Prepetition 2L Credit Agreement.
  • Axip Services, Axip Holdings, and Axip Leasing are each guarantors under the Prepetition Credit Agreements.
  • Axip Leasing owns substantially all of the Debtors' compression units.
• Axip Producer Services - Marcellus I, LLC ("Axip Marcellus"): A wholly owned subsidiary of Axip Services and a guarantor under the Prepetition Credit Agreements.

The non-Debtor affiliates — Axip Gas Solutions GP, LLC; Axip Gas Solutions Partners, LP; Axip MLP Holdings, LLC; Axip Leasing Company II, LLC; and Axip International, LLC — are non-operating entities that hold no assets, generate no revenue for the Debtors, and are not guarantors under any of the Prepetition Credit Agreements.

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Operations Overview

The Company generates revenue by contracting with oil and gas production companies and midstream companies to provide compression services on an initial-term contract that rolls over to a month-to-month arrangement upon expiration. The Company provides its broad national customer base with natural gas and electric compressor units of various sizes, ranging from less than 250 HP to more than 1,500 HP.

Gas Lift Compression

The majority of the Company's compression unit assets — more than 70% — support gas lift services. In a gas lift application, a natural gas or electric compressor injects mechanically compressed, high-pressure natural gas into a well's production stream at the wellhead, forcing fluids below up to the surface and optimizing crude oil production.

• Gas lift compression is relied on by upstream customers and can be utilized either at the wellhead or in centralized compression stations using a broad range of compressor unit sizes.
• Once a well is placed on an artificial lift application such as gas lift, it will typically remain on a lift application for the rest of its productive life.

Gathering Compression

Nearly 30% of the Company's compression units are deployed in gathering applications. Factors such as distance, friction, and volume can contribute to lower pressure, creating an inefficient environment for moving natural gas downstream.

• Gathering compression applications collect lower-pressure natural gas from wells and move it through a compressor unit, mechanically reducing the space the gas occupies, thereby increasing pressure and enabling pipelines to service increased flow rates into trunk lines.

Equipment Deployment and Lifecycle

Once compression services are contracted, the Company selects the appropriate compression unit(s), transports them to the desired site, and supervises installation as the units are connected to the customer's pipelines and facilities.

• A compression unit typically remains in place for two to five years depending on the application, but can be deployed for ten years or more.
• The typical lifespan of a compression unit is approximately 20 to 25 years. After completion of a contract, units are returned to the Company with useful life remaining and sit idle until redeployment.

Electric Compressor Transition

Compression units have historically been powered by siphoning off a small portion of the natural gas available at the well. While the majority of the Company's fleet remains natural-gas powered — as is the case industry-wide — the Company has moved toward offering electric-driven compressors to service the increasing climate-related goals of its customers.

• More than 25% of the Company's compressor fleet is now electric-motor driven.
• Electric compressors offer improved runtime and performance metrics relative to gas-driven counterparts, including automatic and remote-start capabilities that eliminate combustion emissions.
• Electric compressors, however, require certain infrastructure — such as powerlines — to be in place at the well, which is not required for natural-gas compressors.

Field Operations and Maintenance

The Company maintains an experienced staff of approximately 101 field technicians who provide operations and maintenance services for the compressors, including callout help, crash repairs, monthly preventative maintenance, and larger overhauls on years-long intervals.

• Because the Company's compression units are often deployed in rural areas without sufficient local skilled labor, the Company recruits primarily from elsewhere in Texas and New Mexico and provides lodging for employees to work on a set rotation schedule.
• The Company also utilizes a remote monitoring and data analytics program that monitors and optimizes its compressor fleet from wellhead to pipeline in real time, reducing time-intensive manual intervention, associated downtime and flaring, supporting root-cause analysis, and improving resource allocation.
• In addition to its own employees, the Company relies on service partners in the field to provide certain types of repairs or maintenance.

Management

The Company is led by an experienced management team:

• Robert Stiles — President and Chief Executive Officer (3 years with the Company; 45 years of industry experience)
• Stephen Childress — Chief Financial Officer (3 years; 20 years of industry experience)
• Earl Ashley — Vice President, Operations (3 years; 36 years of industry experience)
• Mike Wright — Vice President, Sales & Business Development (5 years; 23 years of industry experience)
• John Guoynes — Vice President, Product Development (3 years; 30 years of industry experience)

The Company's management team is supported by an experienced workforce that is vital to operations, these Chapter 11 Cases, and the Debtors' efforts to maximize estate value. In many instances, these employees are highly trained personnel with specialized skills who are not easily replaced.

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Prepetition Obligations

As of the Petition Date, the Debtors reported approximately $240.5 million in total funded debt liabilities. The Company's prepetition capital structure is comprised of a superpriority term loan, an asset-based revolving facility, a second lien term loan, and trade and other unsecured claims, as summarized below:

Prepetition Superpriority Facility

• Approximately $13.2 million is outstanding under a first lien secured term loan credit facility with JPMorgan Chase Bank, N.A., serving as administrative agent and collateral agent.
  • The facility, entered into on September 23, 2025, provides for an aggregate principal amount of up to $15.7 million. Obligations under the facility are secured by a first-priority lien on substantially all of the Debtors' assets and carry payment priority over the Prepetition ABL Facility.
  • The facility was subsequently expanded through two incremental amendments: a First Incremental Tranche of up to $850,000 (October 2025) and a Second Incremental Tranche of up to approximately $1.9 million (February 2026).
  • Beginning in October 2025, the Debtors entered into a series of forbearance agreements and email extensions with their superpriority lenders, which were repeatedly extended through the Petition Date. In addition to the outstanding principal, the Debtors owe accrued and unpaid interest under the facility.

Prepetition ABL Facility

• Approximately $207.8 million is outstanding under a revolving credit and letter of credit facility governed by a Fourth Amended and Restated Credit Agreement with JPMorgan Chase Bank, N.A., as administrative agent and collateral agent.
  • The facility provided for an initial aggregate revolving commitment of approximately $203.4 million. Obligations under the facility are secured by a first-priority lien on substantially all of the Debtors' assets, subject to the payment priority of the Superpriority Facility.
  • The Debtors entered into two forbearance agreements with their ABL lenders—the first on September 23, 2025, and the second on October 19, 2025—with the second agreement subsequently extended by email on numerous occasions through February 2026. In addition to the outstanding principal, the Debtors owe accrued and unpaid interest under the facility.

Prepetition Second Lien Facility

• Approximately $19.5 million is outstanding under an Amended and Restated Second Lien Term Loan Agreement, dated September 22, 2022, with Permico, Inc., as administrative agent.
  • The facility provided for initial term loans of approximately $17.6 million and has a scheduled maturity date of March 22, 2026.
  • Obligations under the facility are secured by a second-priority lien on substantially all of the Debtors' assets.

Trade and Other Unsecured Claims

• As of the Petition Date, the Debtors estimate approximately $17 million to $20 million in trade claims, representing outstanding accounts payable obligations, including unpaid invoices and other amounts owed for goods and services received in the ordinary course of business.
• The Debtors also have additional general unsecured claims, most of which are believed to be contingent, unliquidated, and/or disputed.
  • The Debtors depend on a network of critical vendors—including specialized parts suppliers, repair and maintenance providers, and essential service and equipment providers—many of whom are sole-source or limited-source suppliers. Any disruption in these relationships could materially impair the Debtors' ability to maintain and deploy their compressor fleet, jeopardize customer relationships, and cause immediate and irreparable harm to the estates.

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Events Leading to Bankruptcy

Post-Acquisition Growth Strategy

• Following its 2022 acquisition by Energy Spectrum, the Company embarked on an ambitious growth strategy centered on three pillars: (a) renewing its focus on contracting for compression services utilizing idle compression units, (b) filling market gaps with large, high-horsepower and electric compression units, and (c) optimizing overall operations.
  • To execute on these initiatives, the Debtors contracted for compression services utilizing idle units and invested in new, larger HP equipment to meet customer demand. In December 2023, the Company purchased 10 new 2,500-HP compression units to be built over the following months, with much of the purchase price paid in cash as construction progressed.
  • Notably, the new-build units were acquired to fulfill specific compression services contracts with an intended customer—not as speculative equipment purchases.
• Despite these growth ambitions, the Company operated under thin margins during this transformative period, leaving the business highly susceptible to large or unexpected shifts in cost or revenue.

Customer Challenges

• In the first quarter of 2024, a major offshore drilling customer operating in the Gulf of Mexico unexpectedly filed for chapter 11 protection in the Southern District of Texas, ultimately liquidating and converting to chapter 7. The fallout was severe:
  • More than 15% of the Debtors' total available HP across 24 compression units was left stranded in the Gulf of Mexico, unable to generate anticipated revenue.
  • The loss cost the Company millions in EBITDA and required significant, unplanned legal expenditures to address related issues.
  • Because the customer's compression units were never returned—a multi-million dollar expense that would normally be borne by the customer—the units could not be economically redeployed. The Debtors sold a subset of the stranded units, while the remainder sat idle in the Gulf.
• Additional customer disruptions compounded the Company's challenges. After one customer was acquired, it shifted its business model from wellhead compression to centralized compression over approximately six months in 2023 and 2024, resulting in the premature return of previously contracted electric wellhead compression units and a further significant decline in EBITDA.
  • Although the returned electric units could theoretically be redeployed, electrical infrastructure across the industry struggled to keep pace with drilling and compression demand in 2024, causing delays in redeployment and limiting the Debtors' ability to offset their losses.

Cost-Cutting Measures

• In response to the confluence of customer-driven challenges, the Debtors took a series of steps to preserve liquidity and meet near-term financial commitments:
  • Capital expenditures were minimized, including deferring certain non-essential preventative maintenance.
  • Operating expenses were curtailed, and zero-hour "make ready" projects—capital expenditures required to prepare idle equipment for new contracts—were halted.
  • The Company closed its offshore office, limited overtime hours, and implemented other cost-reduction measures.

Prepetition ABL Facility Covenant Defaults

• The operational challenges reverberated through the Debtors' financial performance throughout 2024 and into the spring of 2025. The Company relied on borrowings under the Prepetition ABL Facility as its primary liquidity source, operating under cash dominion that permitted the ABL Agent to sweep and apply receivables to the facility balance.
  • During this period, the Debtors employed equity cures as permitted under the Prepetition ABL Credit Agreement to address covenant compliance issues.
  • However, the Company projected that certain financial covenant ratios would no longer be met when tested for the fiscal quarter ending June 30, 2025, and Energy Spectrum was unable to provide equity cures sufficient to address the anticipated shortfalls and defaults.

The Refinancing Process

• Facing a looming maturity and impending covenant defaults, the Debtors engaged Evercore Group, L.L.C. in March 2025 to assist with refinancing the Prepetition ABL Credit Agreement.
  • The Refinancing Process was extensive: Evercore contacted approximately 85 parties, of which roughly 51 executed confidentiality agreements and received initial diligence materials. More than a dozen parties provided indications of interest, and nine advanced to a second round of due diligence.
  • Evercore facilitated the resolution of hundreds of diligence questions through a virtual data room and on calls. Although initially targeted to close in July 2025, the process extended into early September 2025.
  • Despite the breadth of the marketing effort, no party was willing to transact on terms sufficient to meet the Debtors' financial objectives.

Forbearance Agreements and Advisor Engagement

• When the Refinancing Process extended past July 2025 without actionable proposals, the Debtors moved to address the outstanding defaults under the Prepetition ABL Credit Agreement by engaging restructuring counsel Vinson & Elkins LLP and restructuring advisor Ankura Consulting LLC.
  • JPMorgan Chase Bank, N.A., on behalf of itself and certain other holders of prepetition secured debt (the "ABL Lender Group"), had previously retained Simpson Thacher & Bartlett LLP and Huron Consulting Group, Inc. as its advisors.
  • The Debtors and Advisors engaged in extensive arm's-length, good-faith negotiations with the ABL Lender Group and its representatives, ultimately entering into Forbearance Agreements to address outstanding defaults. Energy Spectrum provided additional equity in August 2025 to fund certain interim obligations as the Debtors lacked other capital sources.
• In September 2025, Ben Chesters was appointed Chief Restructuring Officer, and Peter Laurinaitis joined E3 Holdings as an independent member of the executive committee with governing and oversight authority over the Debtors.

Pivot to the Sale Process

• By early September 2025, with the Refinancing Process having proved unsuccessful, the parties pivoted to negotiating a Prepetition Superpriority Credit Agreement to provide the Debtors both time and liquidity to pursue a Sale Process while engaging in contingency planning for a potential chapter 11 filing.
  • The superpriority liquidity was critical: it enabled the Debtors to prepare for an orderly restructuring and conduct an out-of-court Sale Process, rather than be forced into an emergency, value-destructive filing. A freefall chapter 11 filing—without DIP financing or an identified buyer—would have been particularly damaging, as the Debtors had no unencumbered cash with which to pay employees, vendors, service providers, or other administrative expenses.
• Evercore conducted the Sale Process, which was robust and designed to achieve a value-maximizing going-concern transaction:
  • Confidentiality agreements were executed and initial diligence materials provided to approximately 21 parties, with Evercore fielding more than 125 questions through a virtual data room and on calls.
  • At the initial bid deadline, the Debtors received multiple indications of interest. The Company and its Advisors negotiated extensively with bidders to improve and refine bids and maximize competitive tension, with a particular focus on identifying a value-maximizing bid that could be implemented out of court.
• The Debtors attempted to secure additional funding during the process, but the Prepetition Superpriority Lenders and ABL Lenders were unwilling to provide funding outside of a bankruptcy proceeding. To continue operating, the Debtors negotiated access to receivables that had previously been swept under the Prepetition ABL Credit Agreement, though efforts to source third-party funding were unsuccessful.

Stalking-Horse Selection and Chapter 11 Filing

• Ultimately, no bid received in the Sale Process exceeded the amounts owed under the Prepetition ABL Facility. After evaluating all bids, the Debtors and the ABL Lender Group determined that Service Compression, LLC ("SC") had submitted the highest, most actionable, and best bid—though the transaction could not be implemented out of court and would require a chapter 11 process.
  • On February 16, 2026, the Debtors and SC entered into a stalking-horse asset purchase agreement. SC was never granted exclusivity, and the Debtors continued marketing and engaging with interested bidders in parallel, although no superior bid emerged.
• To fund the chapter 11 process, the ABL Lender Group, with JPMorgan Chase Bank, N.A. acting as DIP Agent, agreed to provide a debtor-in-possession loan consisting of:
  • $25,514,587 in new money loans; and
  • Loans representing a roll-up of the full principal amount of the Prepetition Superpriority Loans (including accrued interest) and $66,167,124.94 of outstanding Prepetition ABL Loans—collectively providing critical funding for the Chapter 11 Cases.
• The Debtors commenced these Chapter 11 Cases with the support of the ABL Lender Group to continue the prepetition Sale Process, solicit higher or better offers, and confirm that a sale to SC represents the most value-maximizing path available. The Company intends to expeditiously negotiate definitive sale documentation as necessary and consummate the contemplated transaction.