XRF-FI
Proven Results

Numbers That Move the Needle.

The XRF-FI closed loop delivers measurable outcomes across every phase of the drilling program — from reserves discovered to cost per foot drilled.

+5–30%Well Productivity IncreaseWellSoft AS x NPTLabs
+15%Median PI UpliftNFR case studies
5–10%Drilling Cost ReductionCost per foot, program average
−35%NPT Hours Per WellStuck pipe, washouts, sidetracks

Case Studies

Real programs. Audited data. Operator-verified outcomes.

Permian Basin

Mid-size independent operator

Challenge

Operator was experiencing high NPT rates and inconsistent wellbore placement in the Wolfcamp A, with average lateral landing accuracy below 60% in target zone.

Solution

XRF-FI deployed across a 12-well program. XRF-FI XRF sensors provided real-time Wolfcamp A formation characterization; WellSoft AI optimized geosteering decisions and drilling parameters continuously.

"We'd been chasing the Wolfcamp A for three years with inconsistent results. The closed loop changed the equation — we're now landing 94% of our laterals in zone on the first attempt."

VP Drilling, Permian Basin Operator

Outcomes

Landing Accuracy
58%
94%+36 pts
NPT Rate
18%
6%-67%
Avg. ROP
210 ft/hr
287 ft/hr+37%
Cost per Lateral Foot
$312
$241-23%
Before
After
Delta
DJ Basin

Large E&P, Weld County acreage

Challenge

Operator needed to accelerate development pace while reducing well costs in the Niobrara/Codell stack play. Existing formation evaluation workflow added 3–4 days per well.

Solution

XRF-FI XRF analysis replaced conventional wireline runs for formation evaluation. WellSoft AI ingested real-time XRF data to optimize Niobrara/Codell stack landing and completion intervals.

"Eliminating the wireline evaluation window was the unlock we needed. The XRF data is actually higher resolution — and we get it in real time instead of waiting four days."

Chief Drilling Engineer, DJ Basin Operator

Outcomes

Evaluation Time per Well
3.8 days
0.4 days-89%
Wells per Pad (avg)
6
9+50%
Reserves per Well (BOE)
420K
558K+33%
Drilling Days per Well
22
16-27%
Before
After
Delta
Eagle Ford

Private equity-backed operator

Challenge

PE-backed operator needed to maximize reserve recovery per acre ahead of a planned asset sale. Existing program was leaving significant reserves behind due to imprecise landing in the Lower Eagle Ford.

Solution

XRF-FI closed loop deployed across 8-well program. XRF-FI provided continuous Lower Eagle Ford characterization; WellSoft AI maximized reservoir contact and identified bypassed pay in offset wells.

"The closed loop identified bypassed pay in four of our offset wells that we would have left behind. That alone justified the entire program cost."

CEO, Eagle Ford Operator

Outcomes

Reservoir Contact
71%
96%+25 pts
Bypassed Pay Identified
—
4 wellsNew
EUR per Well (BOE)
680K
890K+31%
Program IRR
22%
34%+12 pts
Before
After
Delta

How We Measure Results

All performance figures are calculated against operator-provided baseline data from the 12 months prior to XRF-FI deployment. Metrics are audited against actual well records and production data.

  • Production uplift figures reflect 12-month cumulative production vs. type curve baseline.
  • Reserve identification figures reflect proved developed producing reserves at time of program completion.
  • Cost reduction figures reflect total well cost per lateral foot, program average.
  • NPT reduction figures reflect non-productive time as a percentage of total drilling time.
Get Started

See What the Loop Can Do for Your Basin

Request a technical assessment with data from your acreage. We'll model projected outcomes based on your formation, well program, and current performance baseline.

Request a Basin Assessment→