HELG Collision Dashboard — Week of May 16, 2026

Weekly run. 8 priority companies. Each card has three outreach tabs — LinkedIn DM, Email Draft, LinkedIn Post. Click Contacts to expand the list. Past Monday runs are at the bottom.

Scanned

Prioritized

High signal (8+)

Contacts

Cold

Warm

Client

Priority Outreach — sorted by signal score

Devon Energy · 5 Cold · 12 Client · 2 Unknown · Permian · 19 contacts

10/10

Devon–Coterra merger closed May 7, 2026Devon Energy press release · May 7, 2026

Reason to reach out

Devon and Coterra closed their all-stock merger on May 7 — nine days ago. The combined Delaware Basin position is the largest pure-play in the basin. JOA re-execution, curative-on-acquired leasehold, and NMOCD compulsory pooling coordination across the now-unified NM footprint start immediately and don't slow-roll. Twelve contacts on the list are already at Client stage, most carrying @coterra.com addresses — they are navigating this integration now. (Source: Devon Energy press release, May 7, 2026)

Primary contact: Scott Richter

LinkedIn DM — send to Scott Richter

Scott — the Devon-Coterra close on May 7 puts a real volume of title and JOA work in motion at once. The combined Delaware Basin positions carry legacy acreage from both companies, and the pooling and curative coordination across that footprint is where the work tends to stack up fastest in the first 90 days. We handle that workflow in the Permian and New Mexico regularly. If any of it is landing on your desk during the integration, worth a quick call. — Ben Holliday, HELG · 210.469.3187

Email subject

Devon-Coterra close — title and JOA work that follows immediately

Email body (swap [First Name] when sending)

Hi [First Name], The Devon-Coterra merger closed May 7. Nine days in, the combined Delaware Basin position is the largest pure-play in the basin, and the immediate title and JOA workflow that follows a close of that scale tends to be where the first 90 days get consumed. Three patterns we see consistently on integrations like this: JOA re-execution across combined operated positions where both companies had different form agreements, curative-on-acquired leasehold that the prior operator hadn't run to ground, and NMOCD compulsory pooling coordination across the now-unified NM footprint where pooling applications straddle legacy Coterra and Devon positions. We handle all three workflows in the Permian and New Mexico. Board Certified in Oil, Gas, and Mineral Law, licensed in Texas and New Mexico, sole focus on energy. If a quick call to compare notes on what's building in your queue would be useful, I'm easy to reach. Ben Holliday Holliday Energy Law Group 210.469.3187 · Ben@HELG.law

Subject + body combined

Subject: Devon-Coterra close — title and JOA work that follows immediately Hi [First Name], The Devon-Coterra merger closed May 7. Nine days in, the combined Delaware Basin position is the largest pure-play in the basin, and the immediate title and JOA workflow that follows a close of that scale tends to be where the first 90 days get consumed. Three patterns we see consistently on integrations like this: JOA re-execution across combined operated positions where both companies had different form agreements, curative-on-acquired leasehold that the prior operator hadn't run to ground, and NMOCD compulsory pooling coordination across the now-unified NM footprint where pooling applications straddle legacy Coterra and Devon positions. We handle all three workflows in the Permian and New Mexico. Board Certified in Oil, Gas, and Mineral Law, licensed in Texas and New Mexico, sole focus on energy. If a quick call to compare notes on what's building in your queue would be useful, I'm easy to reach. Ben Holliday Holliday Energy Law Group 210.469.3187 · Ben@HELG.law

LinkedIn post (broader pattern — no operator name)

When two major Delaware Basin operators merge, the JOA re-execution and curative-on-acquired-position work starts on day one — not when the integration timeline says it should. The land team inheriting the combined acreage faces a title workflow that can't be slow-rolled. The compulsory pooling coordination across a unified NM footprint is typically the piece that moves slowest if it starts late. Worth getting that workflow stood up before the synergy clock starts.

▸Contacts (19) · click to show the list · emails pulled from clients-list.xlsx

Name	Email	Stage
Matt Beavers	No email address found	Cold
Andy Bennett	No email address found	Unknown
Keaton Curtis	Keaton.Curtis@coterra.com	Client
Kevin Gavigan	kevin.p.gavigan@gmail.com, Kevin.Gavigan@coterra.com	Cold
Michael Holiday	Michael.Holiday@coterra.com	Client
Martin Howell	No email address found	Cold
Adam Morgan	Adam.Morgan@coterra.com	Client
Blair Nutter	No email address found	Client
Dylan Park	dylan.park@coterra.com	Client
Colt Parks	No email address found	Cold
Megan Powell	No email address found	Client
Scott Richter	Scott.Richter@coterra.com	Client
Trey Roberson	Trey.Roberson@coterra.com	Client
Ashley St.Pierre	Ashley.StPierre@coterra.com	Client
Tristan Walker	Tristan.Walker@coterra.com	Client
Tristan Walker	No email address found	Cold
Brad Wechsler	Brad.Wechsler@coterra.com	Client
Russell Wickman	Russell.Wickman@coterra.com	Client
Aaron Young	No email address found	Unknown

Diamondback Energy · 19 Cold · 5 Warm · 1 Unknown · Permian · 25 contacts

10/10

Barnett full-scale launch H2 2026 + midstream build-outDiamondback Q1 2026 investor presentation · May 2026 + Energy Transfer Ector County filing

Reason to reach out

Diamondback announced full-scale Barnett development launching H2 2026. Thirty delineation wells this year, ramp to ~100 gross/year in 2027. The fastest Barnett well in company history came in at ~18 days and sub-$400/lateral foot. Energy Transfer is registering the Paloma Compressor Station in Ector County — midstream infrastructure ahead of the ramp. Stacked Barnett/Wolfcamp development across 200,000 net Midland acres creates depth-severance and retained-acreage title work that is not trivial at that pace. (Source: Diamondback Q1 2026 investor presentation, May 2026)

Primary contact: Matt Midkiff

LinkedIn DM — send to Matt Midkiff

Matt — the Barnett full-scale launch in H2 is a program that creates a different kind of title question than Spraberry/Wolfcamp. Depth-severance language in legacy Midland Basin deeds wasn't written for stacked Barnett development at pace. We work that pattern. If any of the title or regulatory questions from the ramp-up are landing on your desk, worth a quick conversation. — Ben Holliday, HELG · 210.469.3187

Email subject

Barnett H2 launch — depth-severance and retained-acreage questions worth getting ahead of

Email body (swap [First Name] when sending)

Hi [First Name], Diamondback's investor presentation this month confirmed full-scale Barnett development launching in H2 2026 — 30 delineation wells this year, target roughly 100 gross wells per year beginning in 2027. The Paloma Compressor Station filing by Energy Transfer in Ector County signals midstream is getting ahead of the ramp. The title work on stacked Barnett/Wolfcamp development across legacy Midland Basin positions surfaces a specific set of questions. Depth-severance language in pre-1970s deeds across that acreage was not written for multi-formation horizontal development. The retained-acreage analysis across 200,000 net acres where both Wolfcamp and Barnett are being developed simultaneously is non-trivial at that pace. We work Midland Basin title regularly. Board Certified in Oil, Gas, and Mineral Law, licensed in Texas and New Mexico. If getting ahead of those questions makes sense, I'd welcome 15 minutes to compare notes. Ben Holliday Holliday Energy Law Group 210.469.3187 · Ben@HELG.law

Subject + body combined

Subject: Barnett H2 launch — depth-severance and retained-acreage questions worth getting ahead of Hi [First Name], Diamondback's investor presentation this month confirmed full-scale Barnett development launching in H2 2026 — 30 delineation wells this year, target roughly 100 gross wells per year beginning in 2027. The Paloma Compressor Station filing by Energy Transfer in Ector County signals midstream is getting ahead of the ramp. The title work on stacked Barnett/Wolfcamp development across legacy Midland Basin positions surfaces a specific set of questions. Depth-severance language in pre-1970s deeds across that acreage was not written for multi-formation horizontal development. The retained-acreage analysis across 200,000 net acres where both Wolfcamp and Barnett are being developed simultaneously is non-trivial at that pace. We work Midland Basin title regularly. Board Certified in Oil, Gas, and Mineral Law, licensed in Texas and New Mexico. If getting ahead of those questions makes sense, I'd welcome 15 minutes to compare notes. Ben Holliday Holliday Energy Law Group 210.469.3187 · Ben@HELG.law

LinkedIn post (broader pattern — no operator name)

Stacked-pay development across 200,000 acres in the Midland Basin Barnett is a different title workflow than what most Permian operators have run before. The depth-severance language in legacy Midland deeds was written for vertical development in the 1950s and 1960s. It wasn't written for 18-day laterals targeting a formation 2,000 feet below the Wolfcamp. Worth the title pass before the bit is running at pace.

▸Contacts (25) · click to show the list · emails pulled from clients-list.xlsx

Name	Email	Stage
Danielle Anderson	ldanderson@diamondbackenergy.com	Cold
Laura Barnett	lbarnett@diamondbackenergy.com	Cold
Jaydan Bird	Jbird@diamondbackenergy.com	Cold
Greg Boggs	gboggs@diamondbackenergy.com	Cold
Randis Butts	No email address found	Cold
Bill Caraway	No email address found	Unknown
Kevin Dickerson	kdickerson@diamondbackenergy.com	Cold
Neil Dufford	No email address found	Cold
Chas Gauthier	cgauth@gmail.com	Warm
Jennifer George	jgeorge@diamondbackenergy.com	Cold
Mandy Hendrix	mhendrix@diamondbackenergy.com	Cold
Jason Henson	jhenson@diamondbackenergy.com	Cold
Tyler Humphries	No email address found	Cold
Joseph Jarke	jjarke@diamondbackenergy.com	Warm
Ryan Kelly	No email address found	Cold
Matt Midkiff	mmidkiff@diamondbackenergy.com	Warm
Matthew Midkiff	No email address found	Cold
Katayoun Mohebkhosravi	kmoheb@diamondbackenergy.com	Cold
Drew Neagle	dneagle@diamondbackenergy.com	Cold
Michael Owen	No email address found	Cold
Kyle Pierce	kpierce@diamondbackenergy.com	Cold
Aaron Tanner	atanner@diamondbackenergy.com	Cold
Chase Van Winkle	cvanwinkle@diamondbackenergy.com	Warm
Andrew Waller	awaller@diamondbackenergy.com	Warm
Amanda Winkler	awinkler@diamondbackenergy.com	Cold

BPX Energy · 6 Cold · 2 Unknown · Eagle Ford · 8 contacts

9/10

Eagle Ford refrac program delivering triple-digit returnsBP Q1 2026 earnings call + BPX operations data · April–May 2026

Reason to reach out

BP's Q1 2026 call confirmed BPX is a strategic portfolio pillar — 8% U.S. shale growth targeted in 2026, Eagle Ford refrac program delivering triple-digit returns. The refrac program on existing Eagle Ford wellbores raises a distinct set of title questions around wellbore conveyance, depth severance, and whether the original lease language covers restimulation zones. All eight contacts currently Cold — pure new-logo opportunity. (Source: BP Q1 2026 earnings call, late April 2026)

Primary contact: Aaron Bloedow

LinkedIn DM — send to Aaron Bloedow

Aaron — BP's Q1 call put BPX's Eagle Ford refrac program front and center. Triple-digit returns on refracs is a compelling number. The title and wellbore-conveyance questions that come with a refrac program on existing wellbores are different from new-drill work — depth severance, restimulation clause language, and what the original lease actually covers. We work that pattern. If any of it is showing up on your desk, worth a quick conversation. — Ben Holliday, HELG · 210.469.3187

Email subject

BPX Eagle Ford refracs — wellbore-conveyance and lease questions worth a look

Email body (swap [First Name] when sending)

Hi [First Name], BP's Q1 call called out BPX's Eagle Ford refrac program as a real portfolio contributor — triple-digit-plus returns. That program is a different title and legal workflow than new-drill work, and it tends to surface specific questions that don't come up on a standard completion. The original Eagle Ford leases from the 2009–2014 boom weren't written with large-scale restimulation programs in mind. The depth-severance language, wellbore-conveyance provisions, and what the lease actually covers when you're restimulating an existing lateral rather than drilling a new one are questions that matter at program scale. We handle Eagle Ford title work in Karnes, DeWitt, and the Reeves County crossover regularly. Board Certified in Oil, Gas, and Mineral Law, licensed in Texas and New Mexico. If a 15-minute read on those questions would be useful as the program scales, I'm easy to reach. Ben Holliday Holliday Energy Law Group 210.469.3187 · Ben@HELG.law

Subject + body combined

Subject: BPX Eagle Ford refracs — wellbore-conveyance and lease questions worth a look Hi [First Name], BP's Q1 call called out BPX's Eagle Ford refrac program as a real portfolio contributor — triple-digit-plus returns. That program is a different title and legal workflow than new-drill work, and it tends to surface specific questions that don't come up on a standard completion. The original Eagle Ford leases from the 2009–2014 boom weren't written with large-scale restimulation programs in mind. The depth-severance language, wellbore-conveyance provisions, and what the lease actually covers when you're restimulating an existing lateral rather than drilling a new one are questions that matter at program scale. We handle Eagle Ford title work in Karnes, DeWitt, and the Reeves County crossover regularly. Board Certified in Oil, Gas, and Mineral Law, licensed in Texas and New Mexico. If a 15-minute read on those questions would be useful as the program scales, I'm easy to reach. Ben Holliday Holliday Energy Law Group 210.469.3187 · Ben@HELG.law

LinkedIn post (broader pattern — no operator name)

Eagle Ford refracs at triple-digit returns are a compelling program. The title work is different than new drills. The original Eagle Ford leases from 2009 to 2014 weren't written with restimulation programs in mind — depth severance language, wellbore conveyance clauses, and what 'production in paying quantities' means on a refrac'd lateral are the questions that surface fastest. Worth the legal read before the program scales.

▸Contacts (8) · click to show the list · emails pulled from clients-list.xlsx

Name	Email	Stage
Aaron Bloedow	No email address found	Cold
Josh Cain	No email address found	Unknown
Stephanie Gannaway	No email address found	Cold
Chris Kirgan	No email address found	Cold
John Krattenmaker	No email address found	Cold
Lauren Ross	No email address found	Cold
Bradley Stephenson	No email address found	Unknown
Kyle Wynn	No email address found	Cold

Permian Resources · 1 Cold · 17 Client · Permian · 18 contacts

9/10

Record Q1 FCF + fastest well in company historyPermian Resources Q1 2026 earnings release · May 7, 2026

Reason to reach out

Permian Resources reported record FCF and the fastest well in company history on May 7 — 2,500 feet per day, $675/lateral foot. Guidance raised to 190–195 MBbls/d. At that drilling pace across Reeves and Reagan County positions, the retained-acreage and stacked-pay title analysis tends to fall behind the bit. Seventeen of 18 contacts are already at Client stage — this is a relationship check-in against a fresh operational signal. (Source: Q1 2026 earnings release, May 7, 2026)

Primary contact: Oliver Cho

LinkedIn DM — send to Oliver Cho

Oliver — 2,500 feet per day is a serious pace. When the bit moves that fast across multi-section Reeves and Reagan positions, the retained-acreage analysis and the stacked-pay Wolfcamp title work tend to stack up behind it. Always happy to compare notes on what's building in your queue. Check in when you have a few minutes. — Ben Holliday, HELG

Email subject

2,500 feet per day — title work at that drilling pace

Email body (swap [First Name] when sending)

Hi [First Name], Permian Resources' Q1 release on May 7 flagged 2,500 feet per day as the fastest well in company history. At $675 per lateral foot and a guidance raise to 190–195 MBbls/d, the program is moving at a pace where the retained-acreage and stacked-pay title work tends to trail the bit rather than precede it. Two questions that tend to surface on Reeves and Reagan programs at that pace: retained-acreage analysis on legacy leasehold where the proration units don't map cleanly to modern multi-section development, and depth-severance language in older deeds where the Wolfcamp stacking wasn't contemplated by the original lessor. As the relationship between our teams has developed, this seemed like a natural check-in point — particularly with the guidance raise and the program tempo holding strong. Quick 15 minutes when it works? Ben Holliday Holliday Energy Law Group 210.469.3187 · Ben@HELG.law

Subject + body combined

Subject: 2,500 feet per day — title work at that drilling pace Hi [First Name], Permian Resources' Q1 release on May 7 flagged 2,500 feet per day as the fastest well in company history. At $675 per lateral foot and a guidance raise to 190–195 MBbls/d, the program is moving at a pace where the retained-acreage and stacked-pay title work tends to trail the bit rather than precede it. Two questions that tend to surface on Reeves and Reagan programs at that pace: retained-acreage analysis on legacy leasehold where the proration units don't map cleanly to modern multi-section development, and depth-severance language in older deeds where the Wolfcamp stacking wasn't contemplated by the original lessor. As the relationship between our teams has developed, this seemed like a natural check-in point — particularly with the guidance raise and the program tempo holding strong. Quick 15 minutes when it works? Ben Holliday Holliday Energy Law Group 210.469.3187 · Ben@HELG.law

LinkedIn post (broader pattern — no operator name)

Drilling at 2,500 feet per day on multi-section Delaware Basin positions is the kind of pace where the title work starts trailing the bit rather than leading it. Retained-acreage analysis on legacy Reeves and Reagan leasehold doesn't get easier the faster the program moves. The stacked-pay Wolfcamp depth-severance questions are the ones that tend to surface last and matter most. Clean title before the well, every time — even when the well only takes three days.

▸Contacts (18) · click to show the list · emails pulled from clients-list.xlsx

Name	Email	Stage
Oliver Cho	Oliver.Cho@permianres.com	Client
Hayden Clyce	Hayden.Clyce@permianres.com	Client
Logan Cooksey	No email address found	Client
Ryan Curry	ryan@vfpetroleum.com	Client
Patrick Godwin	No email address found	Cold
Matthew Gray	Matthew.Gray@permianres.com	Client
Mark Hajdik	mark.hajdik@permianres.com	Client
Kelsi Henriques	Kelsi.Henriques@permianres.com	Client
Jon-aaron House	jon-aaron.house@conocophillips.com	Client
Michael Hurlbut	michael.hurlbut@permianres.com	Client
Trevor Irby	trevor.irby@permianres.com	Client
Sean Johnson	Sean.Johnson@permianres.com	Client
Matt Jordan	matt.jordan@permianres.com	Client
Daniel Koury	Daniel.Koury@permianres.com	Client
Brian Pond	Brian.Pond@permainres.com	Client
Adam Reker	No email address found	Client
Drew Tarwater	No email address found	Client
Alexa Wolf	alexa.wolf@permianres.com	Client

Crescent Energy · 4 Cold · South Texas · 4 contacts

8/10

Q1 2026 record production + Permian integration ahead of scheduleCrescent Energy Q1 2026 earnings release · May 5, 2026

Reason to reach out

Crescent reported record 341 MBoe/d on May 5 and $120M in synergies ahead of schedule. The Vital Energy Permian integration is accelerated, and the SilverBow Eagle Ford program is fully operational. All four contacts are currently Cold — no prior HELG relationship. The dual-basin integration at this pace creates curative-on-acquired-leasehold and multi-section title work that doesn't slow-roll. (Source: Crescent Q1 2026 earnings release, May 5, 2026)

Primary contact: David Hansen

LinkedIn DM — send to David Hansen

David — Crescent's Q1 numbers were strong. Record 341 MBoe/d and $120M in synergies ahead of schedule is a real operational result. Running the Vital Energy Permian integration and the SilverBow Eagle Ford program simultaneously is a title and JOA workflow that stacks up faster than the calendar allows. We work that pattern across both Eagle Ford and the Delaware Basin regularly. Worth a conversation if any of it is landing on your desk. — Ben Holliday, HELG · 210.469.3187

Email subject

Crescent's Q1 record and Permian integration — A&D title work at that pace

Email body (swap [First Name] when sending)

Hi [First Name], Crescent's Q1 release on May 5 — 341 MBoe/d, $120M in synergies ahead of target, Permian integration accelerated — represents a real operational step change from where the company was 18 months ago. Running both the Vital Energy Permian integration and the SilverBow Eagle Ford program simultaneously creates a title and JOA workflow that tends to compress quickly. On the Eagle Ford side, the curative-on-acquired leasehold patterns that surface under the SilverBow positions haven't all been worked through by prior operators. On the Permian side, the Vital Energy leasehold carries its own retained-acreage and multi-section title exposure. We handle A&D due diligence, title opinions, and multi-tract allocation work across both Eagle Ford and the Delaware Basin. Board Certified in Oil, Gas, and Mineral Law, licensed in Texas and New Mexico. If a 15-minute call to compare notes would be useful, I'm easy to reach. Ben Holliday Holliday Energy Law Group 210.469.3187 · Ben@HELG.law

Subject + body combined

Subject: Crescent's Q1 record and Permian integration — A&D title work at that pace Hi [First Name], Crescent's Q1 release on May 5 — 341 MBoe/d, $120M in synergies ahead of target, Permian integration accelerated — represents a real operational step change from where the company was 18 months ago. Running both the Vital Energy Permian integration and the SilverBow Eagle Ford program simultaneously creates a title and JOA workflow that tends to compress quickly. On the Eagle Ford side, the curative-on-acquired leasehold patterns that surface under the SilverBow positions haven't all been worked through by prior operators. On the Permian side, the Vital Energy leasehold carries its own retained-acreage and multi-section title exposure. We handle A&D due diligence, title opinions, and multi-tract allocation work across both Eagle Ford and the Delaware Basin. Board Certified in Oil, Gas, and Mineral Law, licensed in Texas and New Mexico. If a 15-minute call to compare notes would be useful, I'm easy to reach. Ben Holliday Holliday Energy Law Group 210.469.3187 · Ben@HELG.law

LinkedIn post (broader pattern — no operator name)

Record production and integration synergies ahead of schedule sound like good news — and they are. The title work on the other side of a dual-basin integration doesn't wait for the synergy count to settle. Curative-on-acquired Eagle Ford leasehold and Permian multi-section retained-acreage analysis both move on the program timeline, not the integration timeline. Worth getting ahead of both before the next AFE drops.

▸Contacts (4) · click to show the list · emails pulled from clients-list.xlsx

Name	Email	Stage
David Hansen	No email address found	Cold
Glen Hodge	No email address found	Cold
Robert Matusek	No email address found	Cold
Zach Morgan	No email address found	Cold

Mewbourne Oil · 3 Cold · 1 Warm · Permian · 4 contacts

8/10

NMOCD May 13 special docket + new OCD filing rulesNMOCD OCD docket + EMNRD OCD hearing calendar · May 13, 2026

Reason to reach out

NMOCD ran a special docket on May 13. Mewbourne remains one of the most active compulsory pooling applicants in Eddy and Lea counties — Creedence 16/28 and Toto 7/10 Federal Com wells both active on recent dockets. New OCD rules effective October 2025 streamline pooling timelines but add pre-application filing hurdles that have become the primary cause of delay on contested matters. Josh Anderson is already at Warm stage. (Source: NMOCD OCD docket activity, May 13, 2026)

Primary contact: Josh Anderson

LinkedIn DM — send to Josh Anderson

Josh — NMOCD ran a special docket on May 13. The new OCD filing rules from October added pre-application requirements that are showing up as the primary delay driver on contested matters. Mewbourne's docket volume in Eddy and Lea is as high as I've seen it. If the new notice workflow is creating friction on any of the active applications, happy to walk through what we're seeing on similar cases. — Ben Holliday, HELG

Email subject

NMOCD May 13 docket and the new pre-application filing rules

Email body (swap [First Name] when sending)

Hi [First Name], NMOCD ran a special docket on May 13. Mewbourne's docket volume in Eddy and Lea County is among the highest of any operator we track, which makes the new OCD filing rules particularly relevant. The rules that took effect in October 2025 were designed to streamline pooling timelines. What we're seeing in practice: the pre-application filing requirements — specifically the notice workflow and the good-faith negotiation documentation — are now the primary source of delay on contested matters. The NMOCD is granting orders faster on applications where that documentation is clean, and the contested cases are where applicants are treating the pre-application step as an afterthought. Mewbourne's program in Eddy and Lea has enough active applications that tightening the pre-application workflow now is worth the time. We handle NMOCD compulsory pooling proceedings regularly and stay current on what's moving through the docket. If walking through the current notice process would be useful, I'm easy to reach. Ben Holliday Holliday Energy Law Group 210.469.3187 · Ben@HELG.law

Subject + body combined

Subject: NMOCD May 13 docket and the new pre-application filing rules Hi [First Name], NMOCD ran a special docket on May 13. Mewbourne's docket volume in Eddy and Lea County is among the highest of any operator we track, which makes the new OCD filing rules particularly relevant. The rules that took effect in October 2025 were designed to streamline pooling timelines. What we're seeing in practice: the pre-application filing requirements — specifically the notice workflow and the good-faith negotiation documentation — are now the primary source of delay on contested matters. The NMOCD is granting orders faster on applications where that documentation is clean, and the contested cases are where applicants are treating the pre-application step as an afterthought. Mewbourne's program in Eddy and Lea has enough active applications that tightening the pre-application workflow now is worth the time. We handle NMOCD compulsory pooling proceedings regularly and stay current on what's moving through the docket. If walking through the current notice process would be useful, I'm easy to reach. Ben Holliday Holliday Energy Law Group 210.469.3187 · Ben@HELG.law

LinkedIn post (broader pattern — no operator name)

The new NMOCD OCD rules effective October 2025 were sold as a streamlining measure. In practice, the pre-application filing requirements are now the leading cause of delay on contested compulsory pooling cases — not the hearing timeline. If you're filing regularly in Eddy or Lea County, the pre-application notice workflow is the place to tighten before your next filing, not after a contested matter slips.

▸Contacts (4) · click to show the list · emails pulled from clients-list.xlsx

Name	Email	Stage
Josh Anderson	janderson@mewbourne.com	Warm
Brad Dunn	bdunn@mewbourne.com	Cold
Corey Mitchell	cmitchell@mewbourne.com	Cold
Ariana Rodrigues	arodrigues@mewbourne.com	Cold

Riley Permian · 2 Warm · 2 Unknown · OKC · 4 contacts

7/10

Q1 production beat + Targa NM pipeline Q3 2026Riley Permian Q1 2026 earnings release · May 9, 2026 + Targa midstream transaction

Reason to reach out

Riley's Q1 2026 release (May 9) showed production topping the high end of guidance at 35.6 MBoe/d. The Targa NM pipeline is on track for Q3 2026 commercial operations, and 20-plus wells are queued to TIL immediately after. With that many wells staged to come online at once, the curative and regulatory work ahead of the Q3 pipeline event is compressed — particularly on the New Mexico side where NMOCD pooling and spacing coordination matters. Michael Palmer is already at Warm stage. (Source: Riley Permian Q1 2026 earnings, May 9, 2026)

Primary contact: Michael Palmer

LinkedIn DM — send to Michael Palmer

Michael — Riley's Q1 production topped the high end of guidance, and the Targa pipeline is on track for Q3. Twenty-plus wells staged to TIL simultaneously is a compressed curative and regulatory timeline. If any of the New Mexico title or NMOCD coordination work ahead of that event is stacking up, happy to compare notes on what we're seeing on similar programs. — Ben Holliday, HELG

Email subject

Targa Q3 pipeline and 20-plus wells staged to TIL — regulatory timing worth flagging

Email body (swap [First Name] when sending)

Hi [First Name], Riley's Q1 release on May 9 showed production topping the high end of guidance at 35.6 MBoe/d, and the Targa NM gas gathering pipeline is tracking for Q3 2026 commercial operations. Twenty-plus wells staged to TIL at once when the pipeline comes online is operationally efficient — it also creates a compressed regulatory and curative window. On the New Mexico side specifically: wells waiting on a pipeline event sometimes surface NMOCD spacing, pooling, or allocation-well questions that are easier to resolve while the wells are pre-production than after they're online. The curative-on-staged-wells window is narrower than it looks. We handle NMOCD regulatory work and Permian Basin title opinions regularly. Both contacts on the list are at Warm stage, so this is a natural check-in against a real program event. If a quick conversation on what to get ahead of before Q3 would be useful, I'm easy to reach. Ben Holliday Holliday Energy Law Group 210.469.3187 · Ben@HELG.law

Subject + body combined

Subject: Targa Q3 pipeline and 20-plus wells staged to TIL — regulatory timing worth flagging Hi [First Name], Riley's Q1 release on May 9 showed production topping the high end of guidance at 35.6 MBoe/d, and the Targa NM gas gathering pipeline is tracking for Q3 2026 commercial operations. Twenty-plus wells staged to TIL at once when the pipeline comes online is operationally efficient — it also creates a compressed regulatory and curative window. On the New Mexico side specifically: wells waiting on a pipeline event sometimes surface NMOCD spacing, pooling, or allocation-well questions that are easier to resolve while the wells are pre-production than after they're online. The curative-on-staged-wells window is narrower than it looks. We handle NMOCD regulatory work and Permian Basin title opinions regularly. Both contacts on the list are at Warm stage, so this is a natural check-in against a real program event. If a quick conversation on what to get ahead of before Q3 would be useful, I'm easy to reach. Ben Holliday Holliday Energy Law Group 210.469.3187 · Ben@HELG.law

LinkedIn post (broader pattern — no operator name)

Twenty-plus wells staged to turn in line the day a pipeline comes online is an efficient program. It's also a compressed curative and regulatory timeline. The NMOCD spacing and pooling coordination on wells that are ready to produce but waiting on midstream tends to surface title questions that were easier to resolve before the pipeline event than after. Worth running the regulatory review while the wells are waiting — not when they're ready to flow.

▸Contacts (4) · click to show the list · emails pulled from clients-list.xlsx

Name	Email	Stage
Ty Edelen	No email address found	Unknown
Chris Harwi	No email address found	Unknown
Michael Palmer	michaelpalmer@rileypermian.com	Warm
Mark Smith	marksmith@rileypermian.com	Warm

BTA Oil Producers · 9 Cold · 1 Warm · Permian · 10 contacts

7/10

Active dual-state Permian program — private operatorTX RRC + NMOCD docket activity · Q1–Q2 2026

Reason to reach out

BTA is a Midland-based private operator running a 3-rig, 28-well-per-year program across West Texas and Eddy County NM — consistent pace, dual-state exposure. Nine of ten contacts currently Cold. The multi-section title and NMOCD compulsory pooling workflow at that rig count is the same as larger operators face — just with less in-house capacity to resolve it. (Source: TX RRC + NMOCD docket, Q1–Q2 2026)

Primary contact: Alex Beal

LinkedIn DM — send to Alex Beal

Alex — BTA's 3-rig Permian program across West Texas and Eddy County stays consistent. Private operators running dual-state programs at that pace hit the same retained-acreage, multi-section title, and NMOCD pooling questions the majors do — the difference is usually in-house capacity to chase them down. If a conversation on what we're seeing on similar programs would be useful, I'm easy to reach. — Ben Holliday, HELG · 210.469.3187

Email subject

BTA's dual-state Permian program — title and pooling patterns worth a conversation

Email body (swap [First Name] when sending)

Hi [First Name], BTA's 3-rig program across West Texas and Eddy County has maintained a consistent pace — 28 wells per year at that scale is a real operational commitment for a private operator. Private operators running dual-state programs at that rig count typically face the same retained-acreage, multi-section title, and NMOCD compulsory pooling questions as the large public operators. The difference tends to be in-house capacity: the questions arrive at the same pace, but the team resolving them is smaller. Two patterns we see regularly on programs like BTA's: the multi-section lateral work where proration units don't map cleanly to the development program, and the NMOCD pooling applications where the pre-application notice workflow has tightened under the new OCD rules. We handle title opinions, NMOCD regulatory work, and compulsory pooling out of San Antonio and Midland. Sole focus on energy. Board Certified in Oil, Gas, and Mineral Law. If 15 minutes on what we're seeing would be useful, I'm easy to reach. Ben Holliday Holliday Energy Law Group 210.469.3187 · Ben@HELG.law

Subject + body combined

Subject: BTA's dual-state Permian program — title and pooling patterns worth a conversation Hi [First Name], BTA's 3-rig program across West Texas and Eddy County has maintained a consistent pace — 28 wells per year at that scale is a real operational commitment for a private operator. Private operators running dual-state programs at that rig count typically face the same retained-acreage, multi-section title, and NMOCD compulsory pooling questions as the large public operators. The difference tends to be in-house capacity: the questions arrive at the same pace, but the team resolving them is smaller. Two patterns we see regularly on programs like BTA's: the multi-section lateral work where proration units don't map cleanly to the development program, and the NMOCD pooling applications where the pre-application notice workflow has tightened under the new OCD rules. We handle title opinions, NMOCD regulatory work, and compulsory pooling out of San Antonio and Midland. Sole focus on energy. Board Certified in Oil, Gas, and Mineral Law. If 15 minutes on what we're seeing would be useful, I'm easy to reach. Ben Holliday Holliday Energy Law Group 210.469.3187 · Ben@HELG.law

LinkedIn post (broader pattern — no operator name)

Private operators running 28-well-per-year programs across West Texas and Eddy County face the same retained-acreage, multi-section title, and NMOCD compulsory pooling questions the large public operators face. The difference isn't the complexity of the questions — it's the in-house capacity to resolve them at pace. Worth building the outside-counsel relationship before the contested pooling case arrives, not after.

▸Contacts (10) · click to show the list · emails pulled from clients-list.xlsx

Name	Email	Stage
Rex Barker	No email address found	Cold
Alex Beal	alexbeal@btaoil.com	Cold
Emma Bolger	ebolger@btaoil.com	Cold
Grant Cavazos	grantmcavazos@gmail.com	Cold
Collin Christian	collin.christian@btaoil.com	Warm
Adam Davenport	adavenport@btaoil.com	Cold
Wilson Price	wprice@btaoil.com	Cold
Kristeen Ramos	kramos@btaoil.com	Cold
Melinda Tefteller	ltefteller@btaoil.com	Cold
Ryan Weaver	rweaver@btaoil.com	Cold

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