HELG Collision Dashboard — Week of May 19, 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

148

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 day 12 — 750,000 net Delaware Basin acres, integration clock runningDevon Energy press release · May 7, 2026 | Rigzone + BIC Magazine · May 8, 2026

Reason to reach out

Devon-Coterra closed May 7 — twelve days ago. The combined Delaware Basin footprint is ~750,000 net acres and ~863,000 Boe/d pro forma. JOA re-execution, curative-on-acquired leasehold, and NMOCD compulsory pooling coordination across the unified New Mexico position are the Day 1–90 workflow. Former Coterra contacts carrying @coterra.com addresses are now Devon employees navigating this integration. Client-stage relationships are the right entry point for a check-in now. (Source: Devon Energy press release, May 7, 2026)

Primary contact: Scott Richter

LinkedIn DM — send to Scott Richter

Scott — twelve days into the Devon-Coterra integration. The combined Delaware Basin position is ~750,000 net acres, and the JOA re-execution and curative work on acquired leasehold doesn't slow-roll at that scale. NMOCD pooling coordination across the now-unified New Mexico footprint is typically the piece that moves slowest when it starts late. If any of that is landing on your desk, worth a quick call to compare notes. — Ben Holliday, HELG · 210.469.3187

Email subject

Devon-Coterra — day 12 title and regulatory workflow

Email body (swap [First Name] when sending)

Hi [First Name], Twelve days into the Devon-Coterra integration. The combined Delaware Basin footprint — ~750,000 net acres, ~863,000 Boe/d pro forma — is the centerpiece, and the JOA and title workflow on a combined position that size tends to compress quickly. Three patterns we see consistently on integrations at this scale: JOA re-execution across combined operated positions where Devon and Coterra used different form agreements, curative-on-acquired leasehold that predecessor operators hadn't run to ground, and NMOCD compulsory pooling coordination across the now-unified New Mexico footprint where pooling applications straddle legacy Coterra and Devon positions. A number of former Coterra contacts are now Devon employees navigating this. We work all three workflows in the Permian and New Mexico — Board Certified in Oil, Gas, and Mineral Law, licensed in Texas and New Mexico. 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 — day 12 title and regulatory workflow Hi [First Name], Twelve days into the Devon-Coterra integration. The combined Delaware Basin footprint — ~750,000 net acres, ~863,000 Boe/d pro forma — is the centerpiece, and the JOA and title workflow on a combined position that size tends to compress quickly. Three patterns we see consistently on integrations at this scale: JOA re-execution across combined operated positions where Devon and Coterra used different form agreements, curative-on-acquired leasehold that predecessor operators hadn't run to ground, and NMOCD compulsory pooling coordination across the now-unified New Mexico footprint where pooling applications straddle legacy Coterra and Devon positions. A number of former Coterra contacts are now Devon employees navigating this. We work all three workflows in the Permian and New Mexico — Board Certified in Oil, Gas, and Mineral Law, licensed in Texas and New Mexico. 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)

Twelve days post-close on a major Delaware Basin merger is when the Day 1–90 title and JOA workflow reveals what wasn't done before the close. JOA re-execution across combined operated positions where both predecessor companies used different form agreements, curative-on-acquired leasehold that prior operators left open, and NMOCD compulsory pooling coordination across a now-unified New Mexico footprint — all of that runs on the integration timeline, not on when the land team gets to it. The operators who get that workflow stood up early tend to have fewer surprises in Year 2.

▸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

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

9/10

Q1 2026 record FCF + investment grade from all three agencies + $3B unsecured revolverPermian Resources Q1 2026 earnings release · May 7, 2026 | Investing.com earnings call transcript

Reason to reach out

Permian Resources hit record FCF, investment grade from all three agencies, and $725/lateral foot D&C costs — all in Q1. Q2 guidance calls for higher production and capex. At that pace across Reeves and Reagan County positions, retained-acreage and stacked-pay Wolfcamp title work runs concurrent with the bit. Seventeen of 18 contacts are at Client stage — a natural relationship check-in against a real operational milestone. (Source: Q1 2026 earnings release, May 7, 2026)

Primary contact: Oliver Cho

LinkedIn DM — send to Oliver Cho

Oliver — Q1 was a meaningful quarter: record FCF, investment grade from all three agencies simultaneously, and $725 per lateral foot — lowest in the Delaware Basin peer group. When Q2 guidance calls for higher production and capex, the retained-acreage analysis and stacked-pay Wolfcamp title work tend to run alongside the bit rather than ahead of it. Happy to compare notes on what's building in your queue. — Ben Holliday, HELG

Email subject

Q1 record FCF and investment grade — title workflow at Q2 pace

Email body (swap [First Name] when sending)

Hi [First Name], Permian Resources' Q1 release on May 7 covered a lot of ground: record FCF at $0.60 per share, investment grade status from all three agencies simultaneously, $725 per lateral foot D&C costs — lowest among Delaware Basin peers — and total production of 413,000 Boe/d above guidance. Q2 guidance calls for modestly higher oil production and capital expenditures as the program accelerates. At $725 per lateral foot and a guidance raise heading into Q2, the pace is real. Two title patterns that tend to surface on programs moving this fast: retained-acreage analysis on legacy Reeves and Reagan leasehold where proration units don't map cleanly to the current multi-section development program, and depth-severance language in older deeds where the Wolfcamp stacking wasn't contemplated. With seventeen of eighteen contacts at Client stage, this seemed like a natural check-in point — particularly with the investment grade milestone and the Q2 pace holding strong. Quick 15 minutes when it works? Ben Holliday Holliday Energy Law Group 210.469.3187 · Ben@HELG.law

Subject + body combined

Subject: Q1 record FCF and investment grade — title workflow at Q2 pace Hi [First Name], Permian Resources' Q1 release on May 7 covered a lot of ground: record FCF at $0.60 per share, investment grade status from all three agencies simultaneously, $725 per lateral foot D&C costs — lowest among Delaware Basin peers — and total production of 413,000 Boe/d above guidance. Q2 guidance calls for modestly higher oil production and capital expenditures as the program accelerates. At $725 per lateral foot and a guidance raise heading into Q2, the pace is real. Two title patterns that tend to surface on programs moving this fast: retained-acreage analysis on legacy Reeves and Reagan leasehold where proration units don't map cleanly to the current multi-section development program, and depth-severance language in older deeds where the Wolfcamp stacking wasn't contemplated. With seventeen of eighteen contacts at Client stage, this seemed like a natural check-in point — particularly with the investment grade milestone and the Q2 pace 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)

Investment grade from S&P, Moody's, and Fitch in the same quarter, record free cash flow, and $725 per lateral foot in the Delaware Basin. That's a low-cost program moving fast. At that pace across multi-section Reeves and Reagan positions, the retained-acreage analysis on legacy leasehold and the stacked-pay Wolfcamp depth-severance questions tend to surface on the program's timeline — not when the land team schedules them. Clean title before the well, every time.

▸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

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

9/10

BP sells $1.5B Permian + Eagle Ford midstream interests to Sixth StreetSPE Journal of Petroleum Technology · May 2026 | World Oil · February–May 2026

Reason to reach out

BP announced the $1.5B sale of BPX Permian and Eagle Ford midstream interests to Sixth Street — BPX drops from 100% to 51% Permian midstream and 75% to 25% Eagle Ford midstream. That ownership restructuring creates surface agreement and easement questions that intersect with the upstream title, particularly on the Eagle Ford side where the refrac program is running simultaneously. All eight contacts Cold — clean new-logo approach. (Source: JPT/SPE · May 2026)

Primary contact: Aaron Bloedow

LinkedIn DM — send to Aaron Bloedow

Aaron — BP's midstream sale to Sixth Street changes the ownership structure on the pipeline and facility agreements across BPX's Permian and Eagle Ford positions. BPX goes from 100% to 51% in the Permian midstream and 75% to 25% in Eagle Ford. That kind of restructuring surfaces surface-use, easement, and operating-agreement questions that touch the upstream title — particularly on the Eagle Ford side where the refrac program is running concurrently. We work both of those areas regularly. Worth a conversation if any of it is landing on your desk. — Ben Holliday, HELG · 210.469.3187

Email subject

BPX midstream divestiture to Sixth Street — upstream title and surface agreement questions

Email body (swap [First Name] when sending)

Hi [First Name], BP announced the sale of non-controlling midstream interests in BPX's Permian and Eagle Ford operations to Sixth Street for $1.5B. Post-transaction, BPX retains 51% of the Permian midstream (from 100%) and 25% of the Eagle Ford midstream (from 75%) while continuing to operate the upstream positions. Midstream ownership changes in an active producing basin create a specific category of questions that intersect with the upstream title: surface-use agreements and easements written when BPX owned the midstream at higher percentages may need to be reviewed against the new ownership structure, operating agreements between the upstream operator and the now-partially-divested midstream entity need to be confirmed, and on the Eagle Ford side — where the refrac program is running — the interaction between original lease language and the revised midstream structure is worth a look. We handle title opinions, surface agreements, and transactional due diligence across Eagle Ford and the Permian. Board Certified in Oil, Gas, and Mineral Law, licensed in Texas and New Mexico. If a 15-minute conversation on what to get ahead of would be useful, I'm easy to reach. Ben Holliday Holliday Energy Law Group 210.469.3187 · Ben@HELG.law

Subject + body combined

Subject: BPX midstream divestiture to Sixth Street — upstream title and surface agreement questions Hi [First Name], BP announced the sale of non-controlling midstream interests in BPX's Permian and Eagle Ford operations to Sixth Street for $1.5B. Post-transaction, BPX retains 51% of the Permian midstream (from 100%) and 25% of the Eagle Ford midstream (from 75%) while continuing to operate the upstream positions. Midstream ownership changes in an active producing basin create a specific category of questions that intersect with the upstream title: surface-use agreements and easements written when BPX owned the midstream at higher percentages may need to be reviewed against the new ownership structure, operating agreements between the upstream operator and the now-partially-divested midstream entity need to be confirmed, and on the Eagle Ford side — where the refrac program is running — the interaction between original lease language and the revised midstream structure is worth a look. We handle title opinions, surface agreements, and transactional due diligence across Eagle Ford and the Permian. Board Certified in Oil, Gas, and Mineral Law, licensed in Texas and New Mexico. If a 15-minute conversation on what to get ahead of 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 a midstream ownership stake changes hands in a basin where you're also running an active upstream program, the surface agreements and easements that connect the two don't automatically follow the transaction. The operating agreements between the upstream operator and the now-partially-divested midstream entity need to be reviewed against the upstream lease terms. On an active refrac program, that review window is narrower than it looks.

▸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

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

9/10

Barnett full-scale H2 2026 — 30 wells this year, 100 gross/year by 2027, targeting $800/lateral footDiamondback Q1 2026 earnings release + investor presentation · May 5, 2026 | GlobeNewswire | TipRanks

Reason to reach out

Diamondback's Q1 call confirmed Barnett full-scale launch H2 2026 — 30 wells this year, targeting 100 gross/year by 2027, with laterals growing from 11,500 ft to 13,000+ ft. Current well cost at $1,000/lateral foot with a CEO target of $800 via multi-pad. Stacked Barnett/Wolfcamp development across 200,000 net Midland acres creates depth-severance and retained-acreage title work that is not trivial at pace. (Source: Diamondback Q1 2026 earnings, May 5, 2026)

Primary contact: Matt Midkiff

LinkedIn DM — send to Matt Midkiff

Matt — the Barnett numbers from the Q1 call are real: 75 Boe per lateral foot EUR, 1.5 net JV rigs running, targeting 13,000-foot laterals growing toward 15,000. The depth-severance language in legacy Midland Basin deeds wasn't written for stacked Barnett development at that pace. We work that title pattern. If any of those questions are landing on your desk as the program ramps toward 100 wells per year, worth a conversation. — Ben Holliday, HELG · 210.469.3187

Email subject

Barnett H2 2026 — depth-severance and retained-acreage questions at program scale

Email body (swap [First Name] when sending)

Hi [First Name], Diamondback's Q1 call on May 5 confirmed the Barnett program trajectory: 30 delineation wells in 2026, targeting roughly 100 gross wells per year starting in 2027, with average laterals growing from 11,500 to 13,000 feet and a cost target of $800 per lateral foot via multi-pad and 15,000-foot wells. The productivity data is compelling — 75 Boe per lateral foot EUR versus 50 for the Midland core. The title work on stacked Barnett/Wolfcamp development across 200,000 net Midland Basin acres surfaces a specific set of questions. Depth-severance language in pre-1970s deeds across that acreage was not written for multi-formation horizontal development at 13,000-foot laterals. The retained-acreage analysis across legacy positions where both Wolfcamp and Barnett are being developed simultaneously is non-trivial at the pace the program is targeting. We handle Midland Basin title work regularly. Board Certified in Oil, Gas, and Mineral Law, licensed in Texas and New Mexico. If getting ahead of those questions before the program hits full pace makes sense, I'd welcome 15 minutes. Ben Holliday Holliday Energy Law Group 210.469.3187 · Ben@HELG.law

Subject + body combined

Subject: Barnett H2 2026 — depth-severance and retained-acreage questions at program scale Hi [First Name], Diamondback's Q1 call on May 5 confirmed the Barnett program trajectory: 30 delineation wells in 2026, targeting roughly 100 gross wells per year starting in 2027, with average laterals growing from 11,500 to 13,000 feet and a cost target of $800 per lateral foot via multi-pad and 15,000-foot wells. The productivity data is compelling — 75 Boe per lateral foot EUR versus 50 for the Midland core. The title work on stacked Barnett/Wolfcamp development across 200,000 net Midland Basin acres surfaces a specific set of questions. Depth-severance language in pre-1970s deeds across that acreage was not written for multi-formation horizontal development at 13,000-foot laterals. The retained-acreage analysis across legacy positions where both Wolfcamp and Barnett are being developed simultaneously is non-trivial at the pace the program is targeting. We handle Midland Basin title work regularly. Board Certified in Oil, Gas, and Mineral Law, licensed in Texas and New Mexico. If getting ahead of those questions before the program hits full pace makes sense, I'd welcome 15 minutes. Ben Holliday Holliday Energy Law Group 210.469.3187 · Ben@HELG.law

LinkedIn post (broader pattern — no operator name)

Seventy-five barrels of oil equivalent per lateral foot EUR in the Barnett versus fifty in the Midland core — that's the number that drives a hundred-well-per-year program. The title work on stacked Barnett/Wolfcamp development across legacy Midland Basin leasehold is the part that doesn't scale automatically. Depth-severance language in pre-1970s deeds wasn't written for 13,000-foot laterals targeting a formation two thousand feet below the Wolfcamp. Worth the title read before the program is at full 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

Crescent Energy · 4 Cold · Permian · 4 contacts

8/10

Q1 2026 record 341 MBoe/d + Ridgemar Eagle Ford deal + 120% synergy capture ahead of scheduleCrescent Energy Q1 2026 earnings release · May 5, 2026 | Natural Gas Intelligence · May 2026

Reason to reach out

Crescent reported record 341 MBoe/d, $120M in synergies at 120% of target, and is now adding Eagle Ford natural gas acreage through the PE-backed Ridgemar deal — on top of an already active two-basin program. Acquiring PE-backed Eagle Ford acreage means curative-on-acquired leasehold due diligence from day one. All four contacts Cold — no prior HELG relationship. (Source: Crescent Q1 2026 earnings + NatGasIntel, May 2026)

Primary contact: David Hansen

LinkedIn DM — send to David Hansen

David — Crescent's Q1 results were strong, and the Ridgemar Eagle Ford deal adds a new acquisition layer to an already active two-basin program. Adding PE-backed Eagle Ford acreage means curative-on-acquired leasehold and title work that starts on day one of the deal, not on the integration timeline. We work that pattern across both Eagle Ford and the Delaware Basin regularly. If any of it is landing on your desk, worth a conversation. — Ben Holliday, HELG · 210.469.3187

Email subject

Crescent Q1 record + Ridgemar Eagle Ford deal — A&D title work on two tracks

Email body (swap [First Name] when sending)

Hi [First Name], Creescent's Q1 release on May 5 — record 341 MBoe/d, $120M in Permian synergies at 120% of target, and a $500,000-per-well cost reduction versus the prior Vital Energy operator — represents a real operational step change. The Ridgemar Eagle Ford deal adds an A&D layer to an already active program. Acquiring PE-backed Eagle Ford acreage means the curative-on-acquired leasehold due diligence is the first workflow to stand up — PE-backed sellers typically deliver less complete title than public operators, and that gap shows up fastest when the acquisition is in a basin where you're already operating at high completion efficiency. On the Permian side, the integration is right-sized at two rigs versus six in 2025 — well-managed — but the title work on the Vital Energy positions doesn't finish running automatically at that pace. We handle A&D due diligence, title opinions, and curative work across 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 on either track 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 Q1 record + Ridgemar Eagle Ford deal — A&D title work on two tracks Hi [First Name], Creescent's Q1 release on May 5 — record 341 MBoe/d, $120M in Permian synergies at 120% of target, and a $500,000-per-well cost reduction versus the prior Vital Energy operator — represents a real operational step change. The Ridgemar Eagle Ford deal adds an A&D layer to an already active program. Acquiring PE-backed Eagle Ford acreage means the curative-on-acquired leasehold due diligence is the first workflow to stand up — PE-backed sellers typically deliver less complete title than public operators, and that gap shows up fastest when the acquisition is in a basin where you're already operating at high completion efficiency. On the Permian side, the integration is right-sized at two rigs versus six in 2025 — well-managed — but the title work on the Vital Energy positions doesn't finish running automatically at that pace. We handle A&D due diligence, title opinions, and curative work across 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 on either track 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)

A dual-basin operator running Eagle Ford at 85% simulfrac utilization and simultaneously adding PE-backed natural gas acreage through a bolt-on deal has a title and JOA workflow running on two tracks at once. The curative-on-acquired Eagle Ford leasehold from a PE-backed seller is typically less complete than what a public operator delivers — that's the pattern, not the exception. Worth the due diligence pass before the acreage transfers.

▸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

ConocoPhillips · 60 Client · 6 Unknown · Permian · 66 contacts

8/10

$2B Permian Delaware Basin asset sale exploration — legacy Concho + Shell positionsBloomberg · February 20, 2026 | World Oil · February 20, 2026 | Hart Energy

Reason to reach out

ConocoPhillips is exploring a $2B Permian Delaware Basin asset sale — legacy Concho and Shell positions in West Texas and New Mexico. A transaction at that scale generates a full A&D due diligence and title opinion workflow on both sides. The buyer will need Delaware Basin title coverage; COP may benefit from sell-side package preparation. Sixty-six Client-stage contacts in Midland make this a natural conversation on either side of a potential transaction. (Source: Bloomberg, World Oil · February 20, 2026)

Primary contact: Adam Altenhofen

LinkedIn DM — send to Adam Altenhofen

Adam — ConocoPhillips announced in February the exploration of a $2B Delaware Basin asset sale — legacy Concho and Shell positions in West Texas and New Mexico. A package at that scale generates a full A&D title and due diligence workflow on both sides of the transaction. We work that workflow in the Delaware Basin regularly, on both sell-side preparation and buy-side acquisition review. If any of that is relevant to where you sit, worth a conversation. — Ben Holliday, HELG · 210.469.3187

Email subject

ConocoPhillips $2B Permian sale — A&D title workflow on both sides

Email body (swap [First Name] when sending)

Hi [First Name], ConocoPhillips announced in February the exploration of a $2B Delaware Basin asset sale — primarily legacy Concho Resources and Shell Plc positions in West Texas and New Mexico — as part of the broader $5B divestiture program tied to the Marathon Oil acquisition. A transaction at that scale in the Delaware Basin generates a specific title and due diligence workflow: comprehensive A&D title opinions on leasehold that has changed hands at least twice (Concho, then COP, now potentially a third buyer), curative-on-acquired positions that may not have been fully resolved at prior closings, and NMOCD spacing and pooling coordination on the New Mexico side of the portfolio. On the sell-side, a clean package with current title opinions and documented curative tends to reduce buyer discount requests and accelerate closing. On the buy-side, the acquirer needs the same coverage. We handle A&D due diligence and title opinions across the Delaware Basin. Board Certified in Oil, Gas, and Mineral Law, licensed in Texas and New Mexico. With sixty-six Client-stage contacts in Midland, this seemed like a timely check-in. If a 15-minute conversation on the title workflow — on either side — would be useful, I'm easy to reach. Ben Holliday Holliday Energy Law Group 210.469.3187 · Ben@HELG.law

Subject + body combined

Subject: ConocoPhillips $2B Permian sale — A&D title workflow on both sides Hi [First Name], ConocoPhillips announced in February the exploration of a $2B Delaware Basin asset sale — primarily legacy Concho Resources and Shell Plc positions in West Texas and New Mexico — as part of the broader $5B divestiture program tied to the Marathon Oil acquisition. A transaction at that scale in the Delaware Basin generates a specific title and due diligence workflow: comprehensive A&D title opinions on leasehold that has changed hands at least twice (Concho, then COP, now potentially a third buyer), curative-on-acquired positions that may not have been fully resolved at prior closings, and NMOCD spacing and pooling coordination on the New Mexico side of the portfolio. On the sell-side, a clean package with current title opinions and documented curative tends to reduce buyer discount requests and accelerate closing. On the buy-side, the acquirer needs the same coverage. We handle A&D due diligence and title opinions across the Delaware Basin. Board Certified in Oil, Gas, and Mineral Law, licensed in Texas and New Mexico. With sixty-six Client-stage contacts in Midland, this seemed like a timely check-in. If a 15-minute conversation on the title workflow — on either side — 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)

A $2B Delaware Basin divestiture involving legacy Concho Resources and Shell positions in West Texas and New Mexico is a title and A&D due diligence project before it's a transaction. The buy-side needs comprehensive title opinions on Permian leasehold that has changed hands at least twice. The sell-side benefits from a clean package. Both sides of that workflow tend to compress in the final 60 days before signing — worth having outside counsel with Delaware Basin depth in position before the process accelerates.

▸Contacts (66) · click to show the list · emails pulled from clients-list.xlsx

Name	Email	Stage
Marc Acuff	No email address found	Unknown
Adam Altenhofen	adam.altenhofen@conocophillips.com	Client
Stephanie Ashley	stephanie.ashley@conocophillips.com	Client
Brandon Beversdorf	brandon.beversdorf@conocophillips.com	Client
John Bowman	john.e.bowman@conocophillips.com	Client
Henry Calle	henry.calle@conocophillips.com	Client
Mark Carter	mark.carter2@conocophillips.com	Client
Wilson Cash	wilson.cash@conocophillips.com	Client
Jackie Chatterton	jackie.chatterton@conocophillips.com	Client
Matt Darby	matt.darby@conocophillips.com	Client
Brian Dart	brian.c.dart@cop.com	Client
Elisabeth Davis	elisabeth.f.davis@conocophillips.com	Client
Clint Devillier	clint.devillier@conocophillips.com	Client
Melissa Dimit	melissa.dimit@conocophillips.com	Client
Ben Eisterhold	No email address found	Unknown
Debbie Evans	debbie.evans@conocophillips.com	Client
Shaina Ferrell	shaina.j.ferrell@conocophillips.com	Client
Caroline Frederick	caroline.frederick@conocophillips.com	Client
Joseph Geiger	joseph.geiger@conocophillips.com	Client
Kelsey Gilbert	kelsey.gilbert@conocophillips.com	Client
Courtney Goggin	courtney.goggin@conocophillips.com	Client
Kayla Hale	kayla.hale@conocophillips.com	Client
Brian Hall	brian.hall@conocophillips.com	Client
Ashley Hansen	No email address found	Unknown
Eric Hernandez	No email address found	Client
Catie Hill	catie.hill@conocophillips.com	Client
Caroline Hoban	caroline.hoban@conocophillips.com	Client
Jared Hobbs	jared.hobbs@conocophillips.com	Client
Aaron Hunter	aaron.hunter@conocophillips.com	Client
Kevin Irwin	kevin.irwin@conocophillips.com	Client
Davis Johnson	davis.d.johnson@conocophillips.com	Client
Dean Joshua	Josh.Dean@conocophillips.com	Client
Brian Joya	brian.joya@conocophillips.com	Client
Andrew Kendall	Andrew.Kendall@conocophillips.com	Client
Jeff Kliewer	jeff.kliewer@conocophillips.com	Client
Shelley Klingler	No email address found	Unknown
Leah M. Lawdermilk	Leah.M.Lawdermilk@conocophillips.com	Client
Brian Levea	brian.levea@conocophillips.com	Client
Zach Marsh	zach.marsh@concophillips.com	Client
Scott Mcbee	No email address found	Client
Kim Mccarver	kim.r.mccarver@conocophillips.com	Client
Mason Mclenna	No email address found	Client
Kieran Mcmullen	kieran.mcmullen@conocophillips.com	Client
Sarah Midkiff	sarah.h.midkiff@conocophillips.com	Client
Sean Miller	sean.miller@conocophillips.com	Client
Joey Moppert	joey.moppert@conocophillips.com	Client
Becca Morris	becca.morris@conocophillips.com	Client
Jason Parker	jason.c.parker@conocophillips.com	Client
Beth Ryan	beth.ryan@conocophillips.com	Client
Brooks Sitka	brooks.sitka@conocophillips.com	Client
Leslie Rountree Smith	leslie.rountreesmith@conocophillips.com	Client
Benjamin Stecker	ben.stecker@conocophillips.com	Client
Mackayla Stone	mackayla.stone@conocophillips.com	Client
Jeffrey Stout	jeff.s.stout@conocophillips.com	Client
John Stretcher	jsstretcher@gmail.com	Client
Robert Stumpf	No email address found	Client
Maribel Torres	maribel.torres@conocophillips.com	Client
Chad Tshirhardt	No email address found	Unknown
Macie Valles	No email address found	Client
Joann Velasquez	joann.velasquez@conocophillips.com	Client
Chris Virant	No email address found	Client
Steve Virant	No email address found	Unknown
Johnna Williams	johnna.williams@conocophillips.com	Client
Justin Williams	justin.k.williams@cop.com	Client
Cash Wilson	No email address found	Client
Henry Zollinger	henry.zollinger@conocophillips.com	Client

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

7/10

NMOCD May 13 docket may resume today + June 23 OCD Examiner hearing — Bone Spring pooling activeNMOCD OCD hearing calendar + EMNRD docket activity · May–June 2026

Reason to reach out

NMOCD May 13 special docket may be resuming today. June 23 brings Mewbourne cases 25860 and 25862 before the OCD Examiner alongside WPX cases. Bone Spring pooling active in Eddy County, Section 14/15, T18S R29E. New OCD pre-application requirements from October 2025 are the primary delay driver on contested matters. Josh Anderson at Warm stage. (Source: NMOCD OCD docket activity, May–June 2026)

Primary contact: Josh Anderson

LinkedIn DM — send to Josh Anderson

Josh — the May 13 NMOCD docket may be resuming today. June 23 brings cases 25860 and 25862 before the OCD Examiner alongside WPX cases. The Bone Spring pooling in Eddy County has a tight hearing schedule ahead. The new pre-application filing requirements from October are still where most contested matters stall — the notice workflow and good-faith negotiation documentation are where the delay originates, not the hearing itself. If any of the active applications are running into that friction, happy to walk through what we're seeing on similar cases. — Ben Holliday, HELG

Email subject

NMOCD May 13 docket and June 23 OCD Examiner hearing — Bone Spring pooling workflow

Email body (swap [First Name] when sending)

Hi [First Name], NMOCD's May 13 special docket may be resuming today. The June 23 OCD Examiner hearing will bring Mewbourne cases 25860 and 25862 before the examiner alongside WPX cases 26049–26052 — the Bone Spring pooling applications in Eddy County, Section 14/15, Township 18 South, Range 29 East. Mewbourne's docket volume in Eddy and Lea County is among the highest we track. With the new pre-application filing requirements from October 2025 still creating friction on contested matters, the good-faith negotiation documentation and notice workflow are the steps most operators are underinvesting in before filings — and those gaps are showing up as delays in the OCD Examiner phase. We handle NMOCD compulsory pooling proceedings regularly and monitor what's moving through the docket in Eddy and Lea. If walking through the current notice process and the June 23 hearing posture 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 June 23 OCD Examiner hearing — Bone Spring pooling workflow Hi [First Name], NMOCD's May 13 special docket may be resuming today. The June 23 OCD Examiner hearing will bring Mewbourne cases 25860 and 25862 before the examiner alongside WPX cases 26049–26052 — the Bone Spring pooling applications in Eddy County, Section 14/15, Township 18 South, Range 29 East. Mewbourne's docket volume in Eddy and Lea County is among the highest we track. With the new pre-application filing requirements from October 2025 still creating friction on contested matters, the good-faith negotiation documentation and notice workflow are the steps most operators are underinvesting in before filings — and those gaps are showing up as delays in the OCD Examiner phase. We handle NMOCD compulsory pooling proceedings regularly and monitor what's moving through the docket in Eddy and Lea. If walking through the current notice process and the June 23 hearing posture 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 NMOCD pre-application filing requirements that took effect October 2025 were designed to streamline pooling timelines. In practice, the good-faith negotiation documentation and the notice workflow that precede the actual hearing are now where most contested matters stall. If you're filing Bone Spring or Wolfcamp pooling applications in Eddy or Lea County, the pre-application step is the place to get right before the hearing is scheduled — not after a contested case 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

Targa NM pipeline permit 'any day' — 20+ wells staged for simultaneous TIL at Q3 startupRiley Exploration Permian Q1 2026 earnings release + earnings call · May 9, 2026

Reason to reach out

Riley's Q1 call confirmed Targa pipeline permit is expected 'any day,' with a several-month construction period before Q3 commercial operations. Twenty-plus wells staged to TIL simultaneously on startup — the curative and NMOCD coordination window ahead of that event is tight, and the permit could arrive this week. Michael Palmer at Warm stage — a natural check-in now, before the window closes. (Source: Riley Permian Q1 2026 earnings call, May 9, 2026)

Primary contact: Michael Palmer

LinkedIn DM — send to Michael Palmer

Michael — Q1 production topped the high end of guidance and the Targa permit is expected any day. Once that arrives, the construction clock starts and 20-plus wells are in queue for simultaneous TIL. The curative and NMOCD coordination window ahead of a Q3 startup is narrower than it looks from May — particularly on the New Mexico side. If any of that work is building up, happy to compare notes. — Ben Holliday, HELG

Email subject

Targa permit expected any day — regulatory and title window before Q3 TIL

Email body (swap [First Name] when sending)

Hi [First Name], Riley's Q1 call on May 9 confirmed production above the high end of guidance at 35.6 MBoe/d and flagged that the Targa NM high-pressure trunk line permit is expected 'any day.' A several-month construction period follows, with Q3 commercial operations still the target. Twenty-plus wells staged to TIL simultaneously on pipeline startup is an efficient program — it's also a compressed curative and regulatory window. If the permit arrives this week, the clock on that window starts now. On the New Mexico side specifically: the NMOCD spacing, pooling, and allocation-well questions on staged wells are easier to resolve while the wells are pre-production than after the TIL clock is running against a Q3 infrastructure deadline. We handle NMOCD regulatory work and Permian Basin title opinions in New Mexico 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 the permit arrives 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 permit expected any day — regulatory and title window before Q3 TIL Hi [First Name], Riley's Q1 call on May 9 confirmed production above the high end of guidance at 35.6 MBoe/d and flagged that the Targa NM high-pressure trunk line permit is expected 'any day.' A several-month construction period follows, with Q3 commercial operations still the target. Twenty-plus wells staged to TIL simultaneously on pipeline startup is an efficient program — it's also a compressed curative and regulatory window. If the permit arrives this week, the clock on that window starts now. On the New Mexico side specifically: the NMOCD spacing, pooling, and allocation-well questions on staged wells are easier to resolve while the wells are pre-production than after the TIL clock is running against a Q3 infrastructure deadline. We handle NMOCD regulatory work and Permian Basin title opinions in New Mexico 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 the permit arrives 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)

A pipeline permit expected any day, a several-month construction period, and 20-plus wells staged to turn in line simultaneously — that's a compressed regulatory and curative timeline on the New Mexico side. NMOCD spacing and pooling coordination on staged wells is easier to resolve before the pipeline event than after, when the TIL clock is running. The curative window on pre-production wells is narrower than most operators account for when the production date is tied to an infrastructure milestone.

▸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

Past Weekly Runs

Week of 2026-05-16